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Home My WebLink About209-098New Plugback Esets 6/27/2024 Well Name API Number PTD Number ESet Number Date 1J-118 PB1 50-029-23337-70-00 206-176 T39063 2-4-2009 1J-118 PB2 50-029-23337-71-00 206-176 T39064 2-4-2009 1J-136L1 PB1 50-029-23331-71-00 206-155 T39065 2-21-2007 1J-136L1 PB2 50-029-23331-72-00 206-155 T39066 2-21-2007 CD2-76 PB1 50-103-20603-70-00 209-098 T39067 1-13-2010 CD2-76 PB2 50-103-20603-71-00 209-098 T39068 1-13-2010 CD4-24 PB1 50-103-20602-70-00 209-097 T39069 3-24-2010 CD4-24 PB2 50-103-20602-71-00 209-097 T39070 3-24-2010 L-203L3 PB1 50-029-23416-70-00 209-112 T39071 9-24-2010 L-203L3 PB2 50-029-23416-71-00 209-112 T39072 9-24-2010 OP03-P05 PB1 50-029-23396-70-00 208-137 T39073 2-23-2009 OP03-P05 PB2 50-029-23396-71-00 208-137 T39074 2-23-2009 CD2-76 PB1 50-103-20603-70-00 209-098 T39067 1-13-2010 CD2-76 PB2 50-103-20603-71-00 209-098 T39068 1-13-2010 • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. C) 7 - q 2 Well History File Identifier Organizing (done) ❑ Two -sided 111 1111 III 11 III ❑ Rescan Needed III I RES N DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: i Cd ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: f 1 11 /s/ f Project Proofing III 1111111111111 BY: Maria Date: 1 4 /s/ Ii Scanning Preparation 5 x 30 = /7570 + = TOTAL PAGES 77 ( Count does not include cover sheet ) vvi BY: Maria Date: f 1 1 /s/ Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: / 1 78 / (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: M ti aria Date: //nil / / /s/ t o Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 1 ReScanned 11! IIIIIIIIIII 11111 BY: Maria Date: /5/ Comments about this file: Quality Checked III 1111111111111 III 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1 1. Operator: 4a. Well Class: Stratigraphic ❑ Service ❑ 6. Permit to Drill Number: 209 -098 ConocoPhillips Alaska, Inc. Development El Exploratory ❑ 7. Well Name: CD2 -76 2. Address: 4b. Well Status: Oil 0 Gas ❑ WAG ❑ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20603 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 10 or Final ❑ 312 -265 7/25/2012 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: . cement - contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 387* 387 totals (bbls): 2012 / 3rd 0 0 0 0 0 2012/4th 24138 100 0 24238 18 10/12/2012 11/15/2012 CD1 -01A, CD1-47 2013 /1st 2013 / 2nd 2013 / 3rd . Total Ending Report is due on the 20th Volume 24138 100 387 24625 18 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. AP 0 12. Remarks and Approved Substances 9 2013 Description(s): *freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: 744(- a/ Date: ( 6 r Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • • a�6 J (` �� SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 f Re: Colville River Unit, CD2 -76 Sundry Number: 312 -265 Si„ i E AUG u '1022 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above - referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in 20 AAC 25.080 (d) (4), after review of the information provided to demonstrate that compliance with the same drill pad generation and disposal of waste limitation is imprudent, the Commission has determined to authorize disposal of drilling waste through the annular space of a well CD2 -76 not located on the same drill pad as the drilling operation generating the drilling waste wells CD 1 -22B, CD 1 -01, and CD 1 -47. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, i°46-04--/ Cathy P. Foerster Chair DATED this day of July, 2012 Encl. ConocoPhillips Alaska, Inc. • • Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh i l I i s July 17, 2012 RECEIVED Alaska Oil and Gas Conservation Commission JUL 1$ 2012 333 West 7 Avenue, Suite 100 AOGCC �► VVVV Anchorage, Alaska 99501 -3539 11..�� Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD2 -76 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2 -76 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. The anticipated start date for annular disposal operations on CD2 -76 is July 23, 2012. CPA is requesting AOGCC approval to annular dispose of 35,000 bbls of muds and cuttings from the well we are currently drilling CD1 -22B and CD1- 01(new Class 1 disposal well). We will need this approval as soon as possible and to continue to through November 30 This will give us time to sidetrack and complete new Class 1 disposal well in CD1 -01. Please find attached form 10 -403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on 10 -3/4" x 7 -5/8" casing annulus. 11. List of Wells on C]pad and the lateral distance from the surface casing shoe. 12. Information regar mg wells within 1 /4 mile radius at AOGCC: CD2 -02, CD2 -03, CD2- 20,CD2 -12, CD2 -11, CD2 -23, CD2 -15, CD2 -404, CD2 -21, CD2 -24, CD2 -72, CD2 -18, CD2 -31, CD2 -468 and CD2 -09. 13. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations A recent injectivity test conducted on 7/15/2012 shows the annular LOT (13.8 ppg) occurred at a lower equivalent mud weight than the casing shoe FIT (16.6 ppg). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Weifeng Dai at 263 -4324; Chip Alvord can also be reached by calling 265 -6120. Sincerely, Weifeng Dai 90 Drilling Engineer • • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 cnOCOPII Telephone 907 - 276 -1215 Bcc: CD2 -76 Well File Chip Alvord ATO -1577 Sharon Allsup -Drake ATO -1530 • • R %E. STATE OF ALASKA JUL 18 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION AOGCC 20 AAC 25.080 1. Operator 3. Permit to Drill Name: 2090980 . ConocoPhillips Alaska 4. API Number: 50- 103- 20603 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD2 -76 ' 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: CD2 -02, CD2 -03, CD2- 20,CD2 -12, CD2 -11, CD2 -23, CD2 -15, Torok and Seabee formation, shale, siltstone and sandstone ' CD2 -404, CD2 -21, CD2 -24, CD2 -72, CD2 -18, CD2 -31, CD2 - 468 and CD2 -09 b) Waste receiving zone: b) water wells within one mile: Sand layers below the upper Cretaceous C30 marker . None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1711' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None Densities range from diesel to 12ppg 2060 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 23 Jul - 12 added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) Cement Bond Log (if required) ❑ FIT Records w /LOT Graph I Surf. Casing Cementing Data El Other El previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. l J 7 ( 7 ( �f L_ Title: ,4& - 6 , 41t 1 '�`re Signature: /l�� / Printed Phone Name: Chip Alvord Number: 265 -6120 Commission Use Only Conditions of approval: Wiwi T0)2' 01 1"//1 t It P UMP /4!� LOT review and approval: U N 19- sues -zorz Subsequent form required: I 0 4'2 3 Approval number: ■! \ 2 20S APPROVED BY THE COMMISSION Approved by: 9 COMMISSIONER Date: 7....2.s--_/ ,L F W� 0 -4 3A ev. 6/2004 1 SZI ALRUCTIONS ON REVERS'E'BDMS JUL 26 6 ��,;; • ' 'n Duplicat �i • • Annulus Disposal Transmittal Form - Well CD2 -76 AOGCC Regulations, 20 AAC 25.080 (b) 1 Designation of the well or wells to receive drilling wastes: CD2 -76 2 The depth to the base of freshwater aquifers and permafrost, if There are no USDW aquifers in the Colville River Unit. present. Estimated base of Permafrost = 1600' TVD (RKB) 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission finding that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg /1. (Ref. AOGCC Conservation Order No. 443, March 15. 19991 4 A list of all publicly recorded wells within one - quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. ,( well to receive drilling waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12# /gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipment after producing drilling /completion fluid / (see included note from CD1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2060 psi. See attached calculation calculations showing how this value was determined. page. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT / FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: ✓ 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT /FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casing is cemented. l Q /JN(k (0 12 The duration of the disposal operation, not to exceed 90 days. N/A , 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) w h e r e the drilling waste to be disposed of was or CD 1 -22B, CD 1 -01 G 4 7 (a. c J .10-51.4y) will be generated. 15 If the operator proposes not to comply with a limitation N/A 044) o t t i ft � Q f a.x c I established in (d) of this section, an explanation of why ! •JG� � compliance would be imprudent. 0 G D Gv #1 9 20 l 2 16 Any additional data required by the commission to confirm N/A I containment of drilling waste. S'M(7d l�l fe�`t�/ 7dG C4CS ✓ / • • Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) Version 1.0- Jan '05 Well CD2 -76 Assumptions Date 7/17/2012 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi /ft Gas /Fluid Gradient in tubing/casing annulus 0.07 psi /ft Header Pressure (for wells on gas lift) 2,000 psi on G Maximum Fluid Density to avoid Burst of Surface Casing U Pburst85% = PHydrostatic + PApplied - PFormation • 4,425 = ( 2,386 * 0.052 * MWmax ) + 1500 - ( 0.4337 * 2,386 ) O MWmax = 31.9 ppg RECEIVED 2,386 TVD Surface Casing String Size 10.75 in JUL 2 0 2012 Weight 45.5 ppf T. u Grade L 80 AOGCC ° ° ?burst] 5,206 psi t100% ' � Pburst85% 4,425 p si U Depth of Shoe 2,386 ft FIT /LOT @ Shoe 16.6 ppg or 2,060 psi FIT /LOT for Annulus 13.8 ppg Max Surf. Pressure 1,500 psi _ TOC Est. @ 5,097' MD 3,070' TVD Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - PGasGradient - PHeader 4,072 = ( 3,070 * 0.052 * MWmax ) + 1,500 - ( 0.0700 * 3,070) - 2,000 • Z X MWmax = 30 ppg 3.5 "Tubing 2nd Casing String • Size 7.625 in G 6,118 TVD Weight 29.7 ppf Grade L 80 Ycollapse100% 4,790 psi Pcollapse85% 4,072 psi Top of Cement 3,070 ft Gas Gradient 0.07 psi /ft Max Surf. Pressure 1,500 psi Header Press 2,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable = Shoe TVD Depth * .052 * Shoe FIT /LOT Pmax allowable = ( 2,386 * .052 * 16.6 ) Pmax allowable = 2,060 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". • • `tP� Zo �t essure Calculations for Annular Disposal if (for submital with Annular Disposal Application) Version 1.0- Jan '05 Well CD2 -76 Assumptions Date 7/17/2012 Maximum injection pressure of 1,50 psi Maximum density of the injection fluid is .0 ppg Pore pressure at the 9 5/8" casing shoe is 1.434 psi /ft Gas /Fluid Gradient in tubing/casing annulus 0.07 psi /ft Header Pressure (for wells on gas li 2,000 psi cu Maximum Fluid Density to avoid : urst of Surface Casing Pburst85% = PHydrostatic + PApplied - PFo, ation 4, 25 = ( 2,386 * 0.052 * MW , ) + 1500 - ( 0.4337 * 2,386 ) MWmax = 3 ' ppg 2,386 TVD Surfac asing String Si - 10.75 in d t 45.5 ppf Grade L 80 . gyp rburstll.% 5,206 psi Pbur :5% 4,425 psi U 1 D'.th of Sh'e 2,386 ft 3 . T /LOT @ ' oe 16.6 ppg or 2,060 psi FIT /LOT for A nulus 13.8 ppg Max Surf. Pressu e 1,500 psi TOC Est. @ 5,067' MD 3,090' TVD / Maximum Fluid Density avo • Collapse of 2nd Casing String Pcollapse85% = PHydrostatic + PApplied - GasGradient - PHeader 4,072 = ( 3,090 * 0.052 * MWmax ) + 1,500 - ( 0.0700 * 3,090) - 2,000 R Z MWmax = 29.8 ppg 3.5 "Tubing 2nd Casing String Size 7.625 1. 6,118 TV Weight 29.7 p. Grade L 80 rcollapsel0o% 4,790 psi Pcollapse85% 4,072 psi Top of Cement 3,090 ft Gas Gradient 0.07 psi /ft Max Surf. Pressure 1,500 psi Header Press 2,000 psi Maximu Anticipated Pressure at Surface Casing Shoe Pmax allo able = Shoe TVD Depth * .052 * Shoe FIT /LOT Pmax al ,wable = ( 2,386 * .052 * 16.6 ) Pmax allowable = 2,060 psi Thi• is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe ". t WNS III CD -76 ConocoPhillips 0° Well Attributes Max Angle & MD TD Al yr,a . I+1 <,. Wellborn API /UWI Field Name Well Status Inc! p) MD (ftKB) Act Btm (ftKB) calomifangr, 501032060300 ALPINE PROD 69.94 12,734.20 15,769.0 Comment H2S (ppm) Date Annotation End Date KB -Ord (ft) Rig Release Date ••• Well Con59. HORIZONTAL - CO2 -76, 4/29/2011 9:19 26 AM SSSV: TRDP Last WO: 43.87 12/2/2009 r: .Schematic - Actual _ Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 15,500.0 12/24/2010 Rev Reason: GLV C/0 ninam 4/30/2011 HANGER,31 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 14.688 37.0 114.0 114.0 109.00 H-40 Welded Insulated 24" Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 10 3/4 9.950 36.5 3,382.6 2,386.5 45.50 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB)` Set Depth (f... Set Depth (TVD) ... String Wt... String ••• String Top Thrd INTERMEDIATE 75/8 6.875 34.1 12,840.7 6,115.5 29.70 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (6... Set Depth (ND) _. String Wt.. String ... String Top Thrd CONDUCTOR 'LINER 41/2 3.958 12,383.0 15,767.1 7,297.4 12.60 L - 80 SLHT - I Insulated 24 ", Liner Details 37 -114 Top Depth (ND) Top Intl Noml... III Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 12,383.0 5,942.0 66.54 PACKER Baker "HRD" ZXP Liner top packer- 5 -1/2" x 7 -5/8" (6.55" OD x 4.95" ID) 4.950 SAFETY VLV, 12,402.0 5,949.6 66.59 NIPPLE "RS" Packoff Seal Nipple- 5-1/2" (6.06" OD x 4.875" ID) 4.875 2,221 12,404.8 5,950.7 66.59 HANGER Baker Flex- lock liner hanger - 5-1/2" x 7- 50(6.6" OD x 4.83" ID) 4.830 an all 12,414.2 5,954.4 66.61 X0 BUSHING 5.5" x 5" crossover bushing (6.05" OD x 4.47' ID) 4.420 12,417.3 5,955.7 66.62 SBE Baker 5" 80-40 Seal bore extension (5.02" OD x 4.0" ID) 4.000 It 12,435.8 5,962.8 66.59 X0 BUSHING 5" x 4.5" crossover bushing (5.56" OD x 3.92" ID) 3.920 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING4.5x3.5 31/2 2.992 31.2 I 12,434.4 5,962.3 9.30 L - 80 EUE - m Nomi... SURFACE, A • Completion Details 3fi -3,383 p Top Depth (ND) Topincl Top (ftKB) (ftKB) ( °) Item Description Comment !D (in) 31.2 31.2 -0.03 HANGER FMC Tubing Hanger (11 "x 4-1/2 ") 3.958 3.812 3.500 2,221.4 1,925.2 59.25 SAFETY VLV 4 -12" Camco TRM- 4PE /CF SSSV w/ 3.813" DB profile 2,281.2 1,955.0 61.51 XO - Reducing 4.5" 12.6# L -80 IBTM crossover to 3.5" 9.3# L-80 EUE 12,311.0 5,914.2 67.25 NIPPLE CLamco 3 -1/2" DS Nipple (2.813" min ID) (Bore 2.812 ") 2.813 12,415.6 5,955.0 66.62 LOCATOR LOCATOR 2.990 12,422.9 5,957.9 66.63 SEAL ASSY BakerGBH -22 80 -40 Bonded Seal assembly 3.000 GAS LIFT. - IF 5,937 Perforations & Slots II Shot Top (ND) Btm (ND) Dens W Top (ftKB) Bbn (ftKB) (ftKB) (ftKB) Zone Date (sh-.. Type Comment If 15,498 15,518 7,182.7 7,190.3 4/11/2011 6.0 APERF 2.5" GUN, 60 degree phase GAS 11 LI sa i yr, 15,498 15,538 7,182.7 7,198.2 12/20/2009 6.0 IPERF 2.5" MILLENIUM, 60 degree phase t 15,518 15,538 7,190.3 7,198.2 4/10/2011 6.0 RPERF 2.5" GUN, 60 degree phase Notes: General & Safety End Date Annotation or 12/3/2009 NOTE: Well was originally named CD2 -176; changed to CD2 -76 when drilling zone changed GAS LIFT, a „ 12/3/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 12,262 I Ili NIPPLE, 12,311 'i f LOCATOR, / 12,416 TUBING [ Ir ''x1 SPACER, 12,417 SEAL ASSY, ■ t 12,423 ) a I 1 Pi 01V14 '-' Mandrel Details NTERMEDIATE, Top Depth Top Port 34- 12,841 (TVD) Inc! OD Valve Latch Size TRO Run APERF, Stn Top (ftKB) (ftKB) I Make Model (in) Sery Type Type (in) (psl) Run Date Com... 15,498 - 15518'\ 1 5,936.6 3,420.4 68.29 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/1/2009 IPERF, 15,498-15,538 RPE RF, 538 2 11,534.4 5,606.3 67.60 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,779.0 4/28/2011 15,518 - 15,538 3 12,262.0 5,895.5 67.49 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 4/17/2011 LINER, • e 12,383 - 15,787 TD (022.76), 15,789 SURFACE CASING SHOE SEPARATION FROM CD2 -76 CD2 -76 x r Surface Casing Shoe ASP 4 Coordinates: 370069.52 597572245 Distance from Surface egg. Shoe X Surface csg. Shoe Y Surface surface Wells Details@ AOGCC Permit# Permit Date Source well Ann. Vol..... Start Date End Date Object well' Coord. Coord. TVD FIT Ann LOT CD2 -01 9 3059 373114.47 5976019.06 CD2 -02 y 751 369431.33 5976119.22 CD2 -03 Included 1241 37104060 597649642 . CD2-05 9 0 1996 37025860 5973735.40 CD2-06 y NA 0 1569 371610.81 5976018.45 CD2 -07 y NA 0 2222 372218.06 5976287.95 CD2-08 y 2589 372655.88 5975603.76 CD2 -09 y 304 -362 9/30/2004 418 573 370318.00 5978239.00 CO2 -10 5 304 -289 7/30/2004 CO2 -09, CD2-56 30703 8/27/2004 10/15/2004 1754 371800.58 5976006.36 CO2 -11 9 823 37083525 5975420.76 002 -12 y 303 -365 12/12/2003 CD2-57, CD2 -31 32000 5/15/2004 6/14/2004 1039 371071.29 5975445.60 CD2 -13 y 2590 372658.78 5975785.31 CD2 -14 y 301 -288 10/9/2001 CO2 -45, 002 -47, CO2 -32 31073 11/13/2001 3/5/2002 2265 372202.47 5974960.87 CD2 -15 y 301 -308 11/6/2001 002 -50, 002 -25, CD2-44 31852 3/6/2002 9/21/2002 1061 370832.00 5974984.02 CO2 -16 y 2566 372460.34 5974790.01 CO2 -17 y 302 - 122 4/10/2002 0048, CD2 -08 18181 5/29/2002 2/7/2003 2016 371774.00 5974645.00 CD2-18 y 1036 369825.76 5974716.05 CO2 -19 y 303 -083 4/28/2003 CD2 -58, CO252 31337 5/19/2003 6/27/2003 2448 372284 88 597468123 CD2 -20 y 304 -288 7/30/2004 452 1314 371366.14 5975507.11 • 002 -21 y 510 370286.77 597526148 CD2 -22 y 302 -274 9/20/2002 CD2 -08, 002 -36, CD251 31253 2/7/2003 3/16/2003 1984 371678.61 5974562.30 002 -23 y 303 -080 4/28/2003 002 -18, CD2-55, CD2-06 32000 9/4/2003 1/1/2004 1147 371013.17 597507646 CD2 -33 (t-ABB), CD2 -39, CD2 -24 y 301 -186 7/13/2001 CO2 -14, CD2 -15 33999 7/16/2001 10/9/2001 1147 370630.11 5974721.81 CD2 -25 y NA 1967 371594.00 5974479.00 CD2 -26 y 302 - 068 3/4/2002 CD2 -44, CD2 -29, CD2-13 29626 9/7/2002 10/17/2002 2087 371798.52 5974554.55 CD2 -27 y 304 -226 6/23/2004 CD2-53, 002 -05, CD2 -09 32000 7/9/2004 8/27/2004 3986 373046.07 5973071.83 CD2 -28 y 2296 372139.80 5974728.95 2382 18.7 18 002 -29 y 303 -249 8/25/2003 CD2-06, CD2 -30, 002 -27 29036 10/8/2003 11/19/2003 2712 372652.44 5974896.02 CD2 -30 y NA 0 2150 370473.52 5973610.96 CD2-31 y NA 0 1295 369824.37 5974451.30 CD2-32 y 302 - 119 4/30/2002 CO2 -19, CD2-41, 0D2 -23 31113 6/14/2002 7/23/2002 1876 371295.61 5974302.38 CD2-33 B"' y 1838 370155.64 5973886.23 CD2-34 y 302-069 3/4/2002 CD2 -13, CD2 -37 22842 10/17/2002 11/28/2002 2156 371803.06 5974439.79 CD2 -35" 8 2817 372312.31 5974017.68 2385 16 14 CO2 -36 y 303-365 12/12/2003 CD2 -43, CD2 -31, CD2-57 32000 12/31/2003 7/9/2004 2819 371848.22 5973535.38 CD2 -37 y 3219 371569.79 5972874.47 CD2 -38 y 303 - 082 4/28/2003 CD2-40, CD2 -30 30011 7/28/2003 9/4/2003 2946 372033.86 5973527.13 2407 15.8 15.4 CD2 -39 y 301 -281 10/9/2001 CD2 -15, 0D247, CD2-44 29945 10/10/2001 9/16/2002 3093 372350.61 5973633.17 CD2-40 y NA 0 2019 370691.67 5973801.44 CD2-404 y 307 -154 5/8/2007 CD2 -72 6764 5/14/2007 5/31/2007 818 370646.55 5975142.76 2383 18.1 15.6 CO241 y 303 -081 4/28/2003 CD2 -20, CO255,CD243 32000 6/27/2003 7/28/2003 2716 371990.58 5973802.52 CD2 -24, CD2 -33, CD2 - 0O242 y 301 -140 6/1/2001 33A, 002 -15 33992 6/1/2001 10/10/2001 2013 371098.46 5973992.48 00243 y Arctic packed 2219 370344.04 5973520.68 CD2 -44 y 2409 372034.57 5974328.53 00245 y 301 -345 12/13/2001 CD2-49, CD2 -17 22991 1/20/2002 2/19/2002 3280 372765.13 5973853 74 CD2-46 y 302 -273 9/20/2002 CD2-51, CO2 -12 31864 4/15/2003 5/19/2003 2153 371694.80 5974310.85 CD2-47 y 301 -322 12/3/2001 002 -34, CD2 -26 27349 12/17/2001 1/20/2002 2692 371231.72 5973294.19 CD2 -28, CO2 -35o, CD2- 16.4 ann CD2-48 y 302 -275 9/20/2002 45, CO2 -08 32000 12/10/2002 2/4/2003 2527 371631.74 5973736.14 LOT 16.40 CD2-49 y 302 -070 3/4/2002 CO250, 002 -46, CD2 -22 27960 4/22/2002 5/28/2002 2036 371252.38 5974065.93 CD2-50 y 302- 121 4/3012002 CO2-41, CD2 -19, CD2 -16, 32000 7/24/2002 9/7/2002 2186 371665 21 5974227.65 N D251 y 303 -312 10/28/2003 CD2 -07, CD2 -10 31769 11/19/2003 12/24/2003 3822 37311402 5973411.81 02-52 9 NA 3293 372637.61 5973661.63 CD253 y 304 -361 9/30/2004 CD2-56, CD2 -54, 002 -02 26072 10/3/2004 8/5/2005 4280 372896.67 5972509.19 2370 16.00 14.10 00254 y NA 0 2360 369991.09 5973363.59 2373 15.10 13.30 CD2-55 y 2737 371118.23 5973194.84 CD2-56 y 305 -307 10/11/2005 CO2 -404 11167 5/7/2006 5/23/2006 2676 369875.93 5973053.08 CD2 -57 y 305 -238 8/17/2005 002 -01 19181 8/22/2005 9/12/2005 4200 372537.05 5972324.37 2378 17.90 15.90 002 -58 y NA 3677 372102.03 5972657.80 CO259 y 1724 369650.94 5974049.86 2393 15.90 12.30 CD2 -60 y 3593 371269.33 5972336.05 CD2 -75, CD2 -464, CD2 - CD2-72 y 308 -153 4/28/2008 466, 0D2 -463 26564 5/3/2008 7/6/2008 700 369745.64 5975101 63 2394 15.9 12.3 002 -75 308 -213 7/8/2008 CO2 -465, 0D2470 10645 8/22/2008 10/30/2008 2560 369536.59 5973218.56 2390 17.8 15.3 002 -464 3•: - !3/2008 sacked 3049 • 008 : 3/2008 2818 372010.96 597367952 2371 17.7 15.9 CD2-463 n 2492 372243.59 5974504.86 2376 17.2 15.5 CD2 -465 Arctic packed 1433 371259.54 5976521.19 2389 16.6 14.1 002466 y 308 -294 10/23/2009 CD2 -73 15523 7/26/2009 11/1/2009 1532 370684.18 5977125.90 2380 18 13.8 CD2 -467 y 308 -295 10/20/2008 469 18892 11/10/2008 1/10/2009 1422 370335.86 5974325.43 2384 17.5 13.1 002 -468 n 1108 369193.60 5976400 2387 17.9 13.9 CO2 -469 n 2426 369453.78 5973376.17 2390 16.7 16.8 • CD2-470 n 2073 369040.10 5973922.61 2386 17 16.5 CD2 -73 n 1135 369210.81 5974979.59 2384 16 15.5 CO2 -74 n 1383 369260.37 5974601.12 2379 17.2 15.1 CD2 -78 n 2190 369256.11 5973689.42 2370 16.5 15.4 002 -76 n 0 37006952 5975722.49 002 -77 n 3728 371551.00 5972301.20 Planned CD2 76 Name WELLBORE TARGET DETAILS (MAP C60RDINATES) TVDSS +N! -S +EJ -W Northing Easting Shape 12:02, July 17 2012 CD2- 176w Al C 7006.00 9918.66 - 7996.13 5983950.00 1503380.00 Point Quarter View CD2- 176vp07 Alpine C 7123.00 10135.89 - 8159.91 5984170.00 1503220.00 Point 6 3000 \— momm \\ v ■ t 1 2500 h ri ll! M 1 111". 6i . . k • L 8 & _1 0 Y 65 1 -, 0000 •�� z 500 '` • * 1 UL L ‚ t 0 ciAmo ■Nummilm -m -owur IleVe' aim, 24 `1 0 , _,_____ 500 �� .. �.��,�� ice:;. Ilr . ----=4.1*-\0-4 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 West( -) /East( +) (500 ft /in) • • CD2 -176 Surface Casing Well: CD2 -176 10 -3/4" 45.5 ppf L -80 BT -m Casing Date: 10/22/2009 ConocoPhillips Rig: Doyon 19 Alaska, Inc. Depth Jt Number Joints Well Equipment Description and Comments 0 0 Length Tops Page 1 Top of String or Top of Flange Doyon 19 RKB to landing Ring 36.50 FMC Gen V 10 3/4" Casing Hanger 2.18 36.50 Jts 3 to 82 80 Jts 10 -3/4" 45.5 ppf L -80, BTC -m casing 3268.31 38.68 Halliburton "Sure Seal II" Float Collar 1.20 3306.99 Jts 1 to 2 2 Jts 10 -3/4" 45.5 ppf L -80, BTC -m casing 72.13 3308.19 Ray Oil Tools "Silver Bullet" Float Shoe 2.30 3380.32 3382.62 3382.62 3382.62 3382.62 3382.62 13 1/2" Hole to 3393' MD / 2391' TVD 3382.62 10 3/4" Casing Shoe @ 3382' MD / 2386' TVD 3382.62 3382.62 3382.62 90 Joints in Pipe Shed - Ran 82 / Last 8 jts. out 3382.62 3382.62 1 Bowspring Centralizer per Joint 1 -12, then Every Other Joint 14 -80 3382.62 Total 47 Bowsprings - Two Stop Collars 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 3382.62 Remarks: Average MU torque = 8600 Up Wt 202 K Drifted pipe w/ plastic rabbit 9.88" OD Dn Wt 135 K Used Run N Seal dope. Block Wt 80 K Supervisors: David Burley / Granville Rizek • • Security Level: AK Development Daily Drilling Report "e .' CD2 -76 ConocoPhillips Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2009 AFfv -Type NetvmrkllD# , _ _ TataBAF +_Sub - 10265149 11,154, 000.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2 - 76 Development ALPINE 3.88 5.0 0.00 3,393.0 3,393.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 17,994.59 70,490.71 849,208.59 1,663,099.11 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 10/18/2009 10/25/2009 34.99 34.01 0.98 11/21/2009 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 3,382.6ftKB Ops and Depth @ Morning Report 24hr Forecast Picking up/ make up/ stand back 5" drill pipe. Continue to PU /Make up/ standback 5" drill pipe, test BOPE, finish PU 5" drill pipe, MU BHA #2, single in the hole to tag FC @ 3307', test casing. Last 24hr Summary Run 10 - 3/4" 45.5 ppf L -80 BTC -m casing, tagged an obstruction @ 909'. Engage Frank's fillup tool and circulate jt # 23 and #24 down to 980'. Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing to 1835' (jt # 45), circulate 140 bbls (bottom's up +), continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing to 3340' (jt #82). Make up FMC hanger and landing joint, land casing @ 3382', rig down Frank's fillup tool, rig up Dowell cementing head, circulate and condition mud and hole for cement. Lower YP f/ 70 to 19. Hold PJSM. Cement casing w/ Dowell Schlumberger, full returns, 139 bbls 10.7 ppg ASL lead cement to surface, bumped plug to 1050 psi, floats held, CIP © 1457 hrs.- see time breakdown 12:15hrs to 1500 hrs. Rig down cement equipment, nipple down riser, nipple up FMC Alpine II wellhead, verify alignment, test metal to metal seal to 1000 psi f/ 10 minutes. Nipple up BOPE equipment. Pre job safety meeting on picking up 5" drill pipe and standing back in the derrick. Pick up 72 jts of 5" drill pipe /stand back in the derrick, lubricate rig, continue to pickup 9 more joints of drill pipe. General Remarks Weather Head Count No Spills - No Accidents 27 Deg, WC 14, Wind E @ 16 Mph, vis 10 46.0 mile Superursor = ,: Titre Dave Burley, Rig Supervisor Rig Supervisor Granville Rizek, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer T ime Log' Matt End ' ,, Time ====. t th Mart Depth End T Time . (hrs); Phase' Op Cade `.< r Activity Trgl Code T.rb Ctass (E3)' _ -' } t ) " Operator 00:00 01:00 1.00 SURFAC CASING RNCS P 0.0 106.0 Run 10 -3/4" 45.5 ppf L -80 BTC -m casing: Install bow spring on stop 8' above the shoe and on the box of jt # 1, baker lock joint #2, install centralizer on stop 10' below box, bakerlock/ makeup float collar joint w/ centralizer on box of joint #3, bakerlock pin of joint #4. Stab Frank's fillup tool into box of jt #4, then circulate 40 bbls of mud to clear air and check float equipment while still in the conductor. 01:00 02:45 1.75 SURFAC CASING RNCS P 106.0 909.0 Continue to run casing observing makeup mark. Torque casing to 8600 ft lbs of torque. Obtain PU and SO wt's per Rig engineer every 10 joints. Apply Bow spring centralizers on every box to jt #12, then every other box to jt # 80. Ran casing to jt # 23 plus 10' of jt # 24 in the hole, tagged an obstruction (Taking 20k weight) @ 909'. 02:45 03:30 0.75 SURFAC CASING CIRC P 909.0 980.0 Engage Frank's fillup tool and circulate jt # 23 and #24 down. Pumping 5 bpm w/ 250 psi and 29% flow. PU wt 120k, SO wt 105k. Circulated 180 bbls (3 BU). Latest BOP Test Data Date .. 'ammer - . Page 1/5 Report Printed: 7/17/2012 • • Security Level: AK Development k r.Rc. Daily Drilling Report CD2 -76 CoteoPhttleps " ' Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2009 Time Log Start 'r End Dur Time Depth Start Depth End Time t Time (hrs) - Phase= Op' Code - Activity Code = -° P-T-X Trbt Code Trbl Class. -- -_ _- (ftKB) MKS) Operation 03:30 05:00 1.50 SURFAC CASING RNCS P 980.0 1,835.0 Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing. Torque casing to 8600 ft lbs of torque. Obtain PU and SO wt's per Rig engineer every 10 joints. Run from jt #25tojt #45. 05:00 05:30 0.50 SURFAC CASING CIRC P 1,835.0 1,840.0 Engage Frank's fillup tool and circulate jt # 45. Stage pumps up from 2 bpm w/ 270 psi and 17% flow out to 6 bpm w/ 380 psi and 31% flow out. PU wt 141k, SO wt 120k. Circulated 140 bbls ( BU plus). After circulating PU 140k, SO 130k. 05:30 07:45 2.25 SURFAC CASING RNCS P 1,840.0 3,340.0 Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing. Torque casing to 8600 ft Ibs of torque. Obtain PU and SO wt's per Rig engineer. Run from jt # 46 to jt # 82. 07:45 08:00 0.25 SURFAC CASING RNCS P 3,340.0 3,382.6 Make up FMC hanger w/ landing joint. Run in the hole and land on the hanger. PU wt 202, SO wt 135k. 08:00 09:30 1.50 SURFAC CEMENT RURD P 3,382.6 3,382.6 Rig down Franks' fillup tool. Rig up Dowell /Schlumberger cementing head. Bottom seal on cement head would not stay in seal groove - required several attemps to install head. 09:30 12:15 2.75 SURFAC CEMENT CIRC P 3,382.6 3,382.0 Circ and cond. mud for cementing, staged pump rate up from 2.5 bpm / 260 psi to 7 bpm / 350 psi, cond. mud to 10.0 ppg. in and out - lower YP from 70 to 19. St wt up 185K, do wt 148K. Held Prejob safety and opts meeting with rig team. Page 2/5 Report Printed: 7/17/2012 • • Security Level: AK Development Daily Drilling Report ► � : & CD2 -76 c�wec�PYtilli�as Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2009 Tim a Log SCpkt to Dur Time Depth <B) Start Depth End Tie Time:. ; Ihrs Pt e.: Op code - Aed cfy Code P -T X Trbt C ©de Trbt Ctass If KS) operatioir 12:15 15:00 2.75 SURFAC CEMENT CMNT P 3,382.0 3,382.0 Cemented 10 3/4" casing as follows: Rig pumped 99 bbls of 10.0 ppg mud with nut plug marker followed with 33 bbls of Biozan as pre flush w/ nut plug marker. Line up to Dowell and pumped 3 bbls of FW, tested lines to 2500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 5.2 bpm at 180 psi. Mixed & pumped 428 bbls (526 sxs) 10.7 ppg lead slurry at 4.57 yield (ASL) ave. 7.2 bpm at 266 to 136 psi. Observed nut plug marker at shakers w/ 410 bbls lead slurry pumped (pumped down surge can, 428 bbls total) Switched to tail slurry and pumped 57.6 bbls (276 sxs) of 15.8 ppg tail cmt at 1.17 yield (Class G w/ additives) ave. 5.5 bpm at 160 psi. Dropped top plug w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 297 bbls 10.0 ppg mud ave. 7.8 bpm, ICP 230, FCP 700 psi, slowed pump to 4 bpm at 520 psi (for the last 7 bbls of displacement) Bumped plug to 1,050 psi. Checked floats OK, CIP @ 1457 hours. Had full circulation throughout job w/ 139 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 158 bbls of displacement, lost 25K SOW and landed hanger. 15:00 16:30 1.50 SURFAC CEMENT CMNT P 3,382.0 0.0 Blow down cement line - Rig down cement head and line - Rd casing elevators - LD landing joint - Change out casing bails with Drill pipe bails 16:30 18:00 1.50 SURFAC DRILL NUND P 0.0 0.0 Nipple down riser, remove FMC slip lock casing head 18:00 19:15 1.25 SURFAC DRILL NUND P 0.0 0.0 Nipple up FMC Alpine Gen II wellhead. Alignment verified by Rig Supervisor Granville Rizek and FMC rep Rob Wells. Test metal to metal seal to 1000 psi for 10 min. Witness of test by Rig supervisor Granville Rizek and FMC rep Rob Wells. 19:15 20:30 1.25 SURFAC DRILL NUND P 0.0 0.0 Nipple up BOPE stack. Tighten clamp on 1" 5M wellhead. Attatch drain lines. 20:30 20:45 0.25 SURFAC DRILL SFTY P 0.0 Pre job safety meeting prior to rigging up to pick up " drill pipe. 20:45 21:00 0.25 SURFAC DRILL RURD P 0.0 0.0 Rig up to pick up 5" drill pipe from the pipe shed and stand back in the derrick via the mouse hole. 21:00 21:15 0.25 SURFAC DRILL SFTY P 0.0 0.0 Pre job safety meeting on picking up 5" drill pipe. Page 3/5 Report Printed: 7/17/2012 0 • Security Level: AK Development a11-1 " Daily Drilling Report � N vot CD2 - ou ConocoPhillips Report Number: 5 Rig: DOYON 19 Report Date: 10/22/2009 Tl - $tart € ,End Dur Time e Depth Start . Depth End :_ -Time i Time (hrs) Phase COp Code Activity Code P -T-X e Trbl Code Trbl Class. _ - CftKBk (ftKB) Operation =_ . 21:15 23:00 1.75 SURFAC DRILL PULD P 0.0 0.0 Pickup and rabbit 5" "S" and "G" drill pipe to 2.85 ". Stand back in the derrick. A total of 72 jts picked up. 23:00 23:30 0.50 SURFAC DRILL SVRG P 0.0 0.0 Service rig. 23:30 00:00 0.50 SURFAC DRILL PULD P 0.0 0.0 Continue to pickup and rabbit 5" "S" and "G" drill pipe to 2.85 ". Stand back in the derrick. A total of 9 jts picked up. Injection Fluid Fluid Sauirce eee.f From Lease (bbl) Destination: - Vendor, Manifest Number Note Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329516 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329513 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329511 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329510 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329509 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329515 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329512 f/ CD2 -176 Drilling Mud WBM CD2 -176 280.0 CD1 -19 ASRC 329514 f/ CD2 -176 Wetiboresr Weilbore Name Wellbore API /UWI CD2 -76 501032060300 Section= Size=(in) - Act Top (ftKB) Act Bfm MKS.) - Start Date_; - End Date COND1 19 37.0 114.0 SURFAC 13 1/2 114.0 3,393.0 10/19/2009 10/21/2009 INTRM1 9 7/8 3,393.0 12,675.0 10/24/2009 11/2/2009 PROD1 6 3/4 12,675.0 15,769.0 11/21/2009 11/27/2009 Page 4/5 Report Printed: 7/17/2012 • Security Level: AK Development Daily Drilling Report CD2 -76 Report Number: 5 ConocoPhi l ips Rig: DOYON 19 Report Date: 10/22/2009 Casing Strinqs ... - " ' Strug 0P S tring wt Casing Description Run , fin) (Ib in Grade l' Set. Depth (ftk8) Comment - SURFACE 10/22/2009 10 3/4 45.50 L -80 3,382.6 Run 10 -3/4" 45.5 ppf L -80 BTC -m casing: Install bow spring on stop 8' above the shoe and on the box of jt # 1, baker lock joint #2, install centralizer on stop 10' below box, bakerlock/ makeup float collar joint w/ centralizer on box of joint #3, bakerlock pin of joint #4. Stab Frank's fillup tool into box of jt #4, then circulate 40 bbls of mud to clear air and check float equipment while still in the conductor. Continue to run casing observing makeup mark. Torque casing to 8600 ft Ibs of torque. Obtain PU and SO wt's per Rig engineer every 10 joints. Apply Bow spring centralizers on every box to jt #12, then every other box to jt # 80. Ran casing to jt # 23 plus 10' of jt # 24 in the hole, tagged an obstruction (Taking 20k weight) @ 909'. Engage Frank's fillup tool and circulate jt # 23 and #24 down. Pumping 5 bpm w/ 250 psi and 29% flow. PU wt 120k, SO wt 105k. Circulated 180 bbls (3 BU). Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing. Run from jt # 25 to jt # 45. Engage Frank's fillup tool and circulate jt # 45. Stage pumps up from 2 bpm w/ 270 psi and 17% flow out to 6 bpm w/ 380 psi and 31% flow out. PU wt 141k, SO wt 120k. Circulated 140 bbls ( BU plus). After circulating PU 140k, SO 130k. Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing. Run from jt # 46 to jt # 82. Make up FMC hanger w/ landing joint. Run in the hole and land on the hanger. PU wt 202, SO wt 135k. Rig down Franks' fillup tool. Rig up Dowell /Schlumberger cementing head. A total of 47 bow spring centralizers and two stop rings were run. Circ and cond. mud for cementing, reciprocate pipe, staged pump rate up from 2.5 bpm 1260 psi to 7 bpm / 350 psi, cond. mud to 10.0 ppg. in and out - lower YP from 70 to 19. St wt up 185K, do wt 148K. Held Prejob safety and opts meeting with rig team. Had full circulation throughout cement job w/ 139 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 158 bbls of displacement, lost 25K SOW and landed hanger at 1430 hrs. lCeinent Surface Casing Cement - Started @ 10/22/2009 Type Wellbore Cemented String Cement Evaluation Results casing CD2 -76 SURFACE, 3,382.6ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Surface Casing Cement 36.5 3,393.0 4 520.0 Eiuid Class . Amount tsacts) r. V (bet De€isittc gak) == Yiie4d "/ ad€) Est Top (fittEB)- :- Est Btm-(1t1«) Mud w/ nut plug marker 99.0 10.00 Viscosified Water w/ nut plug marker 33.0 8.60 Mud Push II 50.0 10.50 Lead ASL 526 428.0 10.70 4.79 36.5 2,883.0 Tail G w/ add's 276 57.6 15.80 1.16 2,883.0 3,393.0 Page 5/5 Report Printed: 7/17/2012 I PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: 2 -76 Rig: Doyon 19 Date: I 10/24/2009 I Volume Input Volume /Stroke Pump Rate: Drilling Supervisor: I Dave Burley/ Granville Rizek 'Pump used: #2 Mud Pump V Strokes ■ ).1000 Bbls /Strk ■ Strk/min ■ Type of Test: Casing shoe Test LOT /FIT 'V' Pumping down annulus and DP. ■ Casing Test Pressure Integrity Test Hole Size: 9 -7 /8" v 5 Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF: 36.51Ft 3382.61Ft -MD1 2386.411Ft -TVD 3413.01Ft -MD 12398.1IFt -TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 10 -3/4" 45.5 # /Ft L -80 BTC v 0 0 0 3530 0 0 0.00 1030 Casing Test Pressure Integrity t 2 110 1 3525 1 30 0.25 1020 Mud Weight: 9.7 ppg Mud Weight: _ 9.6 ppg 4 270 2 3525 2 90 0.50 1020 Mud 10 min Gel: 51.0 Lb /100 Ft2 Mud 10 min Gel: 40.0 Lb /100 Ft2 6 430 3 3525 3 160 1.00 990 • Test Pressure: 3530.0 psi Rotating Weight: 124000.0 Lbs 8 625 4 3525 4 240 1.50 950 Rotating Weight: 124000.0 Lbs Blocks /Top Drive Weight: 74000.0 Lbs 10 800 5 3525 5 320 2.00 920 Blocks /Top Drive Weight: 74000.0 Lbs Desired PIT EMW: 18.0 ppg 12 910 6 3525 6 390 2.50 890 Estimates for Test: 4 b bls Estimates for Test: 1042 psi _ 1.2 bbls 14 1010 7 3525 7 460 3.00 870 v v 16 1125 8 3525 8 520 3.50 850 EMW = Leak -off Pressure + Mud Weight = 870 + 9 6 PIT 15 Second 18 1240 9 3525 9 570 4.00 840 0.052 x TVD 0.052 x 2386 Shut -in Pressure, psi 20 1375 10 3525 10 620 4.50 820 EMW at 3382.62 Ft -MD (2386.37 Ft -TVD) = 16.6 • • • 1020 22 1495 15 3525 11 670 5.00 810 4000 - 1 Lost 25 psi during test, held 24 1625 20 3520 12 710 5.50 800 99.3% of test pressure. •-• = 26 1760 25 3505 13 750 6.00 790 3500 - ■ -- " --1--A- Iii 28 1900 30 3505 14 810 6.50 790 30 2050 15 870 7.00 3000 32 2200 16 890 7.50 760 34 2360 17 920 8.00 750 w 2500 36 2525 18 950 8.50 750 E - 38 2690 19 980 9.00 750 40 2850 20 1000 9.50 740 2000 42 3025 21 1030 10.00 740 it 1500 44 3200 22 1050 - 46 3360 loon 48 3530 No wellime 500 0 0 1 2 3 4 5 6 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume 'IttCASING TEST -II-LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 4.8 Bbls IBbls 2.2 Bbls IBbls Comments: CD2 -76 Surface LOT -FIT Summary • • CD2 -176 Intermediate Casing Well: CD2 -176 7 -5/8" 29.7 ppf L -80 BTC -m Casing Date: 11/3/2009 ConocoPhillips Rig: Doyon 19 Alaska, Inc. Depth Jt Number Joints 0 Well Equipment Description and Comments Length Tops Page 1 .. Top of String or Top of Flange Doyon 19 RKB to Lower Lockdown Screws 34.08 7 5/8 ", 29.7 #, L -80, BTCM Casing CUTOFF JOINT 3.33 34.08 Jts 186 to 29; 114 Jts 7 5/8" 29.7# L -80 BTCM Casing 4865.12 37.41 TAM Port Collar 2.10 4902.53 Jts 163 to 185 23 Jts 7 5/8" 29.7# L -80 BTCM Casing 973.25 4904.63 Halliburton Stage Collar 2.38 5877.88 Jts 4 to 162 159 Jts 7 5/8" 29.7# L -80 BTCM Casing 6825.89 5880.26 Halliburton Baffle Collar 1.36 12706.15 Jts 3 to 3 1 Jts 7 5/8" 29.7# L -80 BTCM Casing 43.07 12707.51 Halliburton Float Collar w/ By -pass baffle on top .97 12750.58 Jts 1 to 2 2 Jts 7 5/8" 29.7# L -80 BTCM Casing 87.02 12751.55 Silver Bullet Float Shoe 2.14 12838.57 Bottom of Shoe @ » >° 12840.71 12840.71 10 3/4" Shoe 3,382' MD 12840.71 9 7/8" Hole TD @ 16548' MD 12840.71 7 5/8" Shoe @ 12840.71' MD / 6119' TVD 12840.71 12840.71 Total of 34 Tandem Rise Centralizers; Jts 1 -30, 162 -163, 185 -186 12840.71 Total of 34 Stop Rings w/ Bowspring Centralizers 12840.71 Total of 19 Hydro Form Centralizers on Jts 203 -221 12840.71 12840.71 Note: Set Casing in Emergency Slips Due to Differential Sticking 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 12840.71 405 jts in pipe shed / 300 jts to run 12840.71 12840.71 Remarks: Casing drifted with 6.750" Teflon Drift Up Wt 325 K Use Jet IubeRun & Seal pipe dope Dn Wt 160 K Average MU torque 8500 ft /Ibs Block Wt 74 K Supervisors: Dave Burley / Jeff Browning • • Security Level: AK Development Daily Drilling Report CD2 -76 Report Number: 23 ConocoPhillips Rig: DOYON 19 Report Date: 11/9/2009 AVFE Type "" NetwartctlD # Totat AEE +Sup 10265149 11,154, 000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2 - 76 Development ALPINE 21.88 23.0 0.00 16,548.0 16,548.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 37,043.98 893,769.14 210,216.98 6,122,261.13 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 10/18/2009 10/25/2009 34.99 39.55 - 4.56 11/26/2009 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 3,382.6ftKB Ops and Depth @ Morning Report 24hr Forecast Circulating 11,571. Attempting to Regain Returns Run & Cement 7 5/8" Casing Last 24hr Summary Continue to RIH w/ Casing While Pumping t/ 7,520' MD, Had to Work Through Tight Spot at 7,100' MD - CBU X3, Hole Unloaded - RIH w/ Casing While Pumping t/ 8,573' MD - Circ & Condition Mud - RIH w/o Pumping w/ Casing t/ 9,473' MD - Circ & Condition Mud - RIH w/ Casing t/ 9,687' MD, Pipe Differentially Stuck - Worked Pipe Free / Circulated and Conditioned Mud - Spot 50 PPB LCM Pill f/ 9,187' - 8,273' MD - RIH t/ 10,026' MD, Pipe Stuck Out of Slips - Worked Free / Circulated & Conditioned Mud - RIH t/ 11,573' MD General Remarks Weather Head Count No Spills - No Accidents -8 Deg, WC -25, Light Snow, Wind SSW @ 9 50.0 Mph +: Supervisor T Fred Herbert, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Patrick Reilly, Rig Engineer Rig Engineer TFnte Lo m Start: End ° !' € Dt r Time Depth 3tart Depth >End $ Time Time (hrs) Phase op Code;' ' AdiVitidede P -T =x . Trbl Gode - Trbt Class t } ( ) Operation 00:00 01:15 1.25 INTRM1 CASING RNCS P 7,091.0 7,520.0 Continue to RIH w/ Casing t/ 7,520' MD While Pumping 3 BPM @ 230 Psi - Had to Work Through Hard Spot at 7,100' MD, Set 30K Down and Circulated Several Times Prior to "Breaking Through" P/U 217, S/O 140 01:15 04:30 3.25 INTRM1 CASING CIRC P 7,520.0 7,520.0 CBU X3 Staging Pumps Up f/ 3 to 4.5 BPM - Hole Unloaded Cuttings Throughout the Second and Third Circulations, Mostly Sand /Silt w/ Trace Amounts of LCM 04:30 08:15 3.75 INTRM1 CASING RNCS P 7,520.0 8,573.0 Continue to RIH w/ Casing t/ 8,573' MD While Pumping 3 BPM @ 250 Psi P/U 235, S/O 145 08:15 10:30 2.25 INTRM1 CASING CIRC P 8,573.0 8,573.0 Circ & Cond Mud Staging Pumps Up f/ 2.5 to 4.5 BPM 230 to 290 Psi 10:30 12:00 1.50 INTRM1 CASING RNCS P 8,573.0 8,960.0 Continue to RIH w/ Casing t/ 8,960' MD w/ Pumps @ 3 BPM & 250 Psi 12:00 13:45 1.75 INTRM1 CASING CIRC P 8,960.0 8,960.0 Circ & Cond Mud @ 3 BPM w/ 250 Psi - Took 175 to Break Over Before Circulation 13:45 15:00 1.25 INTRM1 CASING RNCS P 8,960.0 9,431.0 RIH w/ Casing (W /O Pumping) t/ 9,431' MD 15:00 15:30 0.50 INTRM1 CASING CIRC P 9,431.0 9,431.0 Circ 90 Bbls @ 3 BPM w/ 280 Psi 15:30 16:15 0.75 INTRM1 CASING RNCS P 9,431.0 9,687.0 RIH w/ Casing t/ 9,687' MD. Tongs broke and had to be repaired. BO the Jt and pipe sat still a for 10 minutes while repairing tongs. Made up next jt and could not move. Pipe Stuck - Circ 30 minutes. Pull 105 Over to Free Pipe. Latest BOP Test Data flats Comment 11 /7/2009 Witness of Test Waived by AOGCC Inspector Grimaldi Page 1/2 Report Printed: 7/17/2012 S • Security Level: AK Development . ►K 1311111 Daily Drilling Report - _ CD2 -76 3 ConocoPttillips Report Number: 23 Rig: DOYON 19 Report Date: 11/9/2009 -Time -Log' - Staa End Duc_, Time Depth Start Depth End Time Ti me (fuss Phase= Dp Code '- Activity Code - P -T -X Trbi Code = Trbl Class.- (ftK6} (ftKB) Operation 16:15 20:15 4.00 INTRM1 'CASING CIRC P 9,687.0 9,687.0 Circ & Cond Mud While Working Pipe - Build 50 PPB LCM Pill of 20 PPB Nut Plug 5, 20 PPB Dyna Red Medium and 10 PPB Sack Black - Spot Tail of LCM Pill in Annulus f/ 9,187' - 8,273' MD. Spot a Lube pill also. 20:15 21:00 0.75 INTRM1 CASING RNCS P 9,687.0 10,026.0 RIH w/ Casing t/ 10,026' MD - Pipe Stuck Coming Out of Slips - Work String to 150 Over Pull, Circ Pumps Up to 5.5 BPM, Shut Pumps Down Pipe Free 21:00 21:45 0.75 INTRM1 CASING CIRC P 10,026.0 10,026.0 Circ 240 Bbls @ 5 BPM w/ 300 Psi 21:45 00:00 2.25 INTRM1 CASING RNCS P 10,026.0 11,573.0 RIH w/ Casing t/ 11,573' MD, P/U 315, S/O 160 Mud Elreck Data YP Cale 'Gel (10s) _ _ Gel (10m) Gel(30m) FITHP Flit Density Temp -_ Solids, Core li Type Depth (ftKB)_ ,, Dens (ib/gai) _ Vs Cs /qt) ' PV Cafc (cp) _ (tbffl O0ft) (tbff100ft=) (Ib111 ) (ibfM00ft') MST (Ib/bbi) (mL/3Omin) pH ( (90)7 LSND w/ 16,548.0 11.80 45 16.0 22.0 9.0 13.0 18.000 25.0 8.8 19.5 Inhybicol LSND w/ 16,548.0 11.80 44 13.0 23.0 9.0 12.0 17.000 20.0 9.2 19.5 Inhybicol Injection Fluid -Fiuid -_ Source - From Lease (bbl) `- Destination - = Vendor Manifest Number Note Diesel CD2 -176 50.0 CD2 -466 Frezze Protect Diesel CD2 -176 10.0 CD2 -466 Periodic Freeze Protect Diesel CD2 -176 5.0 CD2 -466 Injectivity Test Drilling Mud WBM CD2 -176 1000.0 CD2 -466 Water CD2 -176 205.0 CD2 - Flush Welibores Wellbore Name Wellbore APIIUWI CD2 -76 501032060300 - - -- Sectsm =____ _, >=_ Size (ir Act Top (MKS) Act Bart (ftKB) Start Date End Date COND1 19 37.0 114.0 SURFAC 13 1/2 114.0 3,393.0 10/19/2009 10/21/2009 INTRM1 9 7/8 3,393.0 12,675.0 10/24/2009 11/2/2009 PROD1 6 3/4 12,675.0 15,769.0 11/21/2009 11/27/2009 Page 2/2 Report Printed: 7/17/2012 • • Security Level: AK Development Daily Drilling Report i I CD2 -76 Report Number: 24 con ocoPhill ips Rig: DOYON 19 Report Date: 11/10/2009 AFE, 10265149 11,154, 000.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2 - 76 Development ALPINE 22.88 24.0 0.00 16,548.0 16,548.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 8,498.09 902,267.23 173,089.09 6,295,350.22 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 10/18/2009 10/25/2009 34.99 40.55 - 5.56 11/27/2009 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 3,382.6ftKB Ops and Depth @ Morning Report 24hr Forecast Working Differentially Stuck Casing @ 12,847' MD Cement 7 5/8" Casing Last 24hr Summary CBU @ Planned Circulation Point 11,573' MD - Lost Returns After Bottoms Up While Waiting for hale to Clean Up - Work to Get Circulation Back by Reducing Pumps t/ 1/2 BPM and Working Pipe While raising Rate t/ 3 BPM - RIH w/ Casing t/ 12,847' MD - CBU @ Planned Circulation Point - Had Partial Loss of Returns Reduced Pump Rate and Continued to Circ - Attempt to Make Connection @ 12,847' MD Tried to Move Pipe but Differentially Stuck - Pulled up to 200K Over and Re- Established Circulation - Pipe Still Stuck @ Midnight Mud Lost to Formation for Previous 24 Hrs - 423 Bbls General Remarks Weather Head Count No Spills - No Accidents -8 Deg, WC -19, Overcast, Wind SSE @ 5 51.0 Mph Supervisor ,, Title Dave Burley, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Patrick Reilly, Rig Engineer Rig Engineer lime Log Start End Dur Time Depth Start LiDeptkP45 Time Time (hrs) P ",; Op Code Activity Code E -T X f'Trb Cade Trbt,Class. (ftKB) . If p) (Operatiorx 00:00 02:30 2.50 INTRM1 CASING CIRC P 11,573.0 11,573.0 CBU Staging Pumps Up f/ 1 to 4 BPM - Hole Unloaded Cuttings (Sand, Clay & LCM) at Bottoms Up 02:30 06:30 4.00 INTRM1 CASING CIRC T Lost Other 11,573.0 11,573.0 Lost Circulation After Bottoms Up While Circulation Pumping 4 BPM @ 300 Psi - Flow Decreased f/ 19 % to 0% on flow indicator. (full returns to partial returns) - Reduced Pump Rate to 1/2 BPM, Then Increased Gradually to 1 1/2 BPM on the Down Stroke and 3 BPM on the Up - Pumped 35 Bbl 50 PPB LCM Pill - Full Returns Regained and Pumps Eased Up f/ 1 1/2 to 3 BPM on the Down Stroke with Full Returns Maintained - Calculated 128 Bbls Pumped Into the Formation 06:30 08:00 1.50 INTRM1 CASING RNCS P 11,573.0 12,847.0 RIH w/ Casing t/ 12,847' MD - P/U 340, S/O 158 08:00 12:00 4.00 INTRM1 CASING CIRC P 12,847.0 12,847.0 CBU Staging Pumps Up f/ 1 to 3 BPM w/ 290 - 360 Psi - Noted Diminished Returns Flow Out Dropped f/ 19 to 9% at Bottoms Up Mud Lost for Tour 149 Bbls Latest BOP Test Data Date Consnent 11/7/2009 Witness of Test Waived by AOGCC Inspector Grimaldi Page 1/2 Report Printed: 7/17/2012 _ • • Security Level: AK Development Daily Drilling Report =� l` CD2 -76 ContocoPhlili Report Number: 24 Rig: DOYON 19 Report Date: 11/10/2009 Time Log Start' End!! Dur Time Depth Start Depth End - -- - T'une = -Tune (hrs) -- Phase CO Code Activity Cade P-T-X - Trbl Code Trial Class. _ -- = (11KB1 (StKB) Operation 12:00 18:45 6.75 INTRM1 CASING RNCS T Stuck Pipe Differentially 12,847.0 12,847.0 M/U 1 Jt of Tubing and Attempt to RIH - Stuck Attempt to work Pipe Up and Down Setting Down to Block Weight and Pulling Up to 200 w/ No Affect - Lost Circulation Returns Dropped to 0% on Mud Watch & Only a Slight Stream of Mud Visible Going Down the Flow Line - Closed Rams and Attempt to Circulate 10 Bbls Down Back Side @ 2 BPM 200 Psi - Open Rams and Circulate Conventionally @ 3 BPM w/ 300 Psi - Regained Full Returns - Continue to Work Pipe - Pulled a Maximum Indicated Weight of 550K Measured Pipe Stretch: 150K = 0 ", 200K = 7.5 ", 250K = 22 ", 300K = 38.5 ", 350K = 52 ", 400K = 67" 18:45 00:00 5.25 INTRM1 CASING CIRC T Stuck Pipe Differentially 12,847.0 12,847.0 Shut Down Pumps and Monitor Flow Stuck Back to Confirm Breathing - 26 Bbls Returned in 25 Minutes w/ Rates Decreasing f/ 120 to 60 BPH - Circ and Condition Mud While Lowering Mud Weights .2 to 11.6 PPG - Continue to Work Pipe Pulling Up to 425K w/ Pumps @ 3 BPM and 525K w/ Pumps Off and Slacking Off to Block Weight Mud Lost for Tour - 274 Bbls Mud Check ©ata YP CaI Get (lOs) Gel- (10m) : Gel (30m) - KT}-LP Fitt Density TerriAi Solids, Corr Type Depth. (fKB) = Dens ( 80 = Vis (skit) PV Cale (c$ (tbfI1 Doff), (lbt11 OOftt) (1bf/100W) ` (ibf/l O0ft') MBT (lb/Obi) (mtl3omin) Eiti ON (°F) (%)' LSND w/ 16,548.0 11.70 45 14.0 19.0 6.0 12.0 17.000 20.0 7.0 9.1 19.5 Inhybicol LSND w/ 16,548.0 11.80 50 14.0 24.0 10.0 13.0 19.000 20.0 9.2 19.5 Inhybicol injection Fluid Flpid - Source '' From Lease (131)1)- Destination Vendor ManifestNumber Note Diesel CD2 -176 10.0 CD2 -466 Periodic Freeze Protect Weilbore Name Wellbore API /UWI CD2 -76 501032060300 S eetiat �' Size(in) ActTop= (ftKB) ActBtrn(ttKB) Start:, Date - - - End-Date COND1 19 , 37.0 114.0 SURFAC 13 1/2 114.0 3,393.0 10/19/2009 10/21/2009 INTRM1 9 7/8 3,393.0 12,675.0 10/24/2009 11/2/2009 PROD1 6 3/4 12,675.0 15,769.0 11/21/2009 11/27/2009 Page 212 Report Printed: 7/17/2012 • • Security Level: AK Development Daily Drilling Report CI . �� °llw� CD2 -76 Cr�ncate�Phlili Report Number: 25 k Rig: DOYON 19 Report Date: 11/11/2009 AFE Tarps. NetwnrtcllD # - - TotatAFE #Sup 10265149 11,154,000.00 Welibore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD2 - 76 Development ALPINE 23.88 25.0 0.00 16,548.0 16,548.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 4,695.46 906,962.69 166,526.46 6,461,876.68 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 10/18/2009 10/25/2009 34.99 41.55 - 6.56 11/28/2009 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) INTERMEDIATE, 12,840.7ftKB Ops and Depth @ Morning Report 24hr Forecast Allowing Well to Exhale (.5 BPH Currently) Cut Casing - L/D 5" DP - P/U 4" DP - Test BOPE Last 24hr Summary Continue to Circulate and Condition Mud Lowering Mud Weight to 11.6 PPG While Working the Casing Pulling Up to 200K Over and Setting Down to Block Weight - R/U and Cement First Stage w/ 60.7 BBIs of 15.9 PPG Class G - Close Pipe Rams Due to Breathing and WOC - Open HES Stage Collar, CBU and Cement 2nd Stage Through Collar w/ 44 Bbis of 15.9 PPG Class G Cement - Close Stage Collar and Pipe Rams - WOC General Remarks Weather Head Count No Spills - No Accidents 7 Deg, WC -16, Blowing Snow, Wind ENE @ 51.0 28 Mph Supervisor r Title Dave Burley, Rig Supervisor Rig Supervisor Jeff Browning, Rig Supervisor Rig Supervisor Patrick Reilly, Rig Engineer Rig Engineer lime.. t, Stark„ End Dur Time Oepth a, DepthEx rune Time_ - 'a) Phase Op Code Antivity sde - P4 X . Trt l Cade Trhl Class f S3 - (t - - Operetrian 00:00 04:30 4.50 INTRM1 CASING CIRC T Stuck Pipe Differentially 12,844.0 12,844.0 Circulate & Cond Mud to Lower MW to Stuck 11.6 f/ 11.8 PPG - Work Pipe Up & Down Pulling to 550K w/ Pumps Off and 420K w/ Pumps @ 3 BPM the Setting Down to Block Weight - No Effect - Well Breathing w/ Pumps Off 04:30 07:30 3.00 INTRM1 CASING CIRC T Stuck Pipe Differentially 12,844.0 12,844.0 Circulate 3 bpm / 280 psi with 11.6 ppg Stuck mud wt. in & out - Continue working stuck pipe to 420k PUW with pumps on and Staging up to 550K PUW with pumps off - slacking off to block wt. - No Movement 07:30 07:45 0.25 INTRM1 CASING SFTY T Stuck Pipe Differentially 12,844.0 12,844.0 PJSM - on laying down casing Stuck 07:45 08:45 1.00 INTRM1 CASING PULD T Stuck Pipe Differentially 12,844.0 12,844.0 Lay down joint #301 - lay down fill up tool Stuck - blow down top drive 08:45 09:30 0.75 INTRM1 CEMENT RURD P 12,844.0 12,844.0 Rig up cement head and lines - establish circulation - 3 bpm / 270 psi I I Latest BOP Test Data 11/7/2009 Witness of Test Waived by AOGCC Inspector Grimaldi Page 1/3 Report Printed: 7/17/2012 . • Security Level: AK Development Daily Drilling Report CD2 -76 t�,atvff'leitl6s Report Number: 25 Rig: DOYON 19 Report Date: 11/11/2009 time Log: Start End. _ - Dur = - ° - Time Depth Start Depth End Tithe ' Time (tus) Pty= Op Code Activity Code P-T-X - ' Trbt Code Trbl Class. (ItKB) -__'- _ -_ (ftKB) Q Aeration 09:30 13:30 4.00 INTRM1 CEMENT CMNT P 12,844.0 12,844.0 Line up to cementers - pumped 4 bbls of CW100 - test lines to 4000 psi - continue pumping CW100 20 bbls total - Pumped 47 bbls of 12.5 ppg MudPush @ 4 bpm / 420 psi - shut down bled lines and cement head - load 1st stage top plug in head - pumped out plug with last 5 bbls of Mudpush - 52 bbls total - Pumped 295 sxs G cement w/ adds. (60.7 bbls) @ 4 bpm 447 - 211 psi - dropped top plug - Dowell displaced with 20 bbls of FW - switch to rig pumps and displaced with 11.6 ppg mud @ 4 bpm / 300 - 240 psi for first 485 bbls - increased rate to 5 bpm (25 bbls of MudPush around shoe) 320 - 540 psi - slowed rate to 3.5 bpm @ 400 psi for last 4 bbls pumped (total 562 bbls mud) - bumped plug to 1000 psi - CIP @ 1312 hours - Full returns while cementing - Observed well breathing - shut in well with pipe rams @ 1315 hours to avoid potential contamination of cement. Checked floats, held. Blow down cement lines - Install gauge on casing and monitor pressures - SICP 5 psi, SI annulus pressure 35 psi. Cemented casing with shoe @ 12,844', FC @ 12,751', Baffle Collar @ 12,706', stage Collar @ 5878' and port Colar @ 4902' 13:30 19:30 6.00 INTRM1 CEMENT WOC T Stuck Pipe Differentially 12,844.0 12,844.0 Close Rams - Wait On Cement - Stuck Monitor Annular/ Casing Pressures - Initail Annular / Casing Pressure = 25 / 5 Psi - Final Annular / Casing Pressure 30 /160 Psi 19:30 21:00 1.50 INTRM1 CEMENT CIRC P 12,844.0 12,844.0 Pressure Up Casing t/ 3650 Psi and Shift - J Open HES Stage Collar - CBU @ 4 BPM w/ 290 Psi 21:00 22:45 1.75 INTRM1 CEMENT CMNT P 12,844.0 12,844.0 Perform 2nd Staae Cement as Follows: V Dowell Pumped 20 Bbls CW 100 @ 4 BPM, 22 Bbls of Mud Push @ 4 BPM, 44 Bbls of 15.9 PPG Class G Cement @ 4 BPM, Drop HES "Closing" Plug, Pump 20 bbls Fresh Water - Displace Cement w/ 248 Bbls of Mud - Plug on Seat at 2,480 Strokes - Pressure Up Casing t/ 2380 Psi - Collar Closed & Pressure Held @ 2340 Psi f/ 3 Minutes - CIP @ 2245 hrs - Calculated TOC 4 729 MD - ,5;4 of Volume Pumped During Cement Job Returned (101 of 106 Bbls) 22:45 00:00 1.25 INTRM1 CEMENT WOC T Stuck Pipe Differentially 12,844.0 12,844.0 Close Pipe Rams - Wait on Cement Stuck Page 2/3 Report Printed: 7/17/2012 • • Security Level: AK Development ►�r',_ Daily Drilling Report '7'17 6 114M - 0411, CD2 -76 ConocoPhillips Number: 25 p . Rig: DOYON 19 Report Date: 11/11/2009 MudCheck €lata YP CaCt Get(10s) °, - Get_(10m)� Ge[ -(30m} f Fitt t3eeisity Temp € SOW Corr Types - � Depth (ftKB) Dens (Ib /ga 'Vs (sfgt) Kt Cale (cp) Qb_f 1O0 ) . ''(Ibfl1904 (Ibrelgr),,,, , (bfliOert” ' MBT (10.10 _==(nt/30mirt}: °pH - - ( "F} ,;' =(%)- LSND w/ 16,548.0 11.60 46 15.0 23.0 10.0 15.0 19.000 21.0 9.3 19.0 Inhybicol Welibares +' - .. Wellbore Name Wellbore API /UWI CD2 -76 501032060300 ' Section Size (in) ' Act, Top (ftKB) Act Btm viks)' Start.Oate: - - €nd_Date= COND1 19 37.0 114.0 SURFAC 13 1/2 114.0 3,393.0 10/19/2009 10/21/2009 INTRMI 9 7/8 3,393.0 12,675.0 10/24/2009 11/2/2009 PROD1 6 3/4 12,675.0 15,769.0 11/21/2009 11/27/2009 Casing Strings String OD '_ String" Wt Casing Description !` Run Date , (tn) _ (!tall[)- String Grade Set Depth (ftKB) Comment : INTERMEDIATE 11/11/2009 7 5/8 29.70 L -80 12,840.7 Changed drilling zone, backed up & sidetracked out window @ 12675' Cement Intermediate Casing Cement - Started @ 11/11/2009 Type Wellbore Cemented String Cement Evaluation Results casing CD2 - 76 INTERMEDIATE, 12,840.7ftKB Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 1 Intermediate Casing Cement 11,840.0 12,841.0 4 400.0 ,Ruid Class :__ Amount"(sacks) 'f V'(bbt) „ „= ` , Density (tbigat) `.. yield ,(ft.ts etty '''_ Est.TOp-(ftKIl t_=> . Est Bim:;(f1KB Tail Cement G 295 60.7 15.80 1.16 11,840.0 12,840.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl /... P (final) (psi) 2 Isolate Reservoir 5,078.0 5,880.0 4 47.0 FltJt - -Claw - - -- Amount_(aack ”' V(bbl)''. `- Density (ibleat),, yieiCiTrisacq. i - 1.1 -, .'::: 1 :::2M!!!::Eet,,Tepq'ttV•41: '' ; Est Btm ffiKB) ° , , , Tail Cement G 210 43.0 15.60 1.16 5,078.0 5,878.0 Page 3/3 Report Printed: 7/17/2012 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD2-76 Rig: Little Red Date: I 7/15/2012 1 Volume Input - Pump Rate: Drilling Supervisor: D. Mickey Pump used: Other - See Comment Barrels 1 W Bbls /strk Bbl /min Type of Test: Annulus Leak Off Test for Disposal Adequacy ■ Pumping down annulus and DP. ■ Casing Test Pressure Integrity Test Hole Size: 9 - 7/8" V 5 Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF:I I Ft 3382.61Ft -MDR 2386.4IFt -TVD1 3413. IFt -MD I2398.1IFt -TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 10 -3/4" 45.5 # /Ft L -80 BTC V 0 0 0 0 500 0 990 Changes for Annular Adequacy Test Pressure IntegrityTest 2 110 1 0.5 505 1 930 Enter outer casing shoe te: 9.7 in comments Mud Weight: 6.8 ppg 4 270 2 1 540 2 920 Casing description referen 51.0 casing string. Inner casing OD: 40.0 In. 6 430 3 1.5 570 3 900 Hole Size is that drilled bel 3530.0 casing. 124000.0 8 625 4 2 610 4 9 Use estimated TOC for He 124000.0 74000.0 10 800 5 2.5 650 5 8 Enter inner casing OC 74000.0 Desired PIT EMW: 15.5 ppg 12 910 6 3 720 6 880 Estimates for Test: 1080 psi -21.9 bbl 14 1010 7 3.5 790 7 880 '__] -I_ 16 1125 8 4 830 8 865 EMW = Leak -off Pressure + Mud Weight = 870 + 6 8 PIT 15 Second 18 1240 9 4.5 860 9 860 0.052 x TVD 0.052 x 2386 Shut -in Pressure, psi 20 1375 10 5 930 10 860 (2386.37 Ft-TVD) EMW at 3382.62 Ft -MD 2386.37 Ft -TVD = 13.8 22 1495 15 5.5 970 15 830 4000- 24 1625 20 6 1020 20 820 26 1760 25 6.5 1060 25 800 3500 28 1900 30 7 1020 30 790 �� 30 2050 7.5 1020 � � = = == 32 2200 8 1020 3000 �� ∎ ∎�� ■� ■■ 34 2360 8.5 �==== w 2500 � ∎�� 36 2525 9 1000 CL mommiems■■=11wwwm 38 2690 9.5 990 u) 2000 T�� 40 2850 10 990 u) ��r_∎ 42 3025 ill w - - - - -- 44 3200 - - -- a 1500 - - ====== 46 3360 - - - - -- 48 3530 ��= = - - -- 1 000 -- - , --- ..+ ∎ ∎■ '.Or ,i - ririr.- i ��i�irme.�� - - - - -� - - - - -- 500 -- 0 10 20 30 40 50 60 0 5 10 15 20 25 30 Barrels Shut -In time, Minutes Volume Volume Volume Volume [tCASING TEST -0-LEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 48.0 Bbls I Bbls 10.0 Bbls I Bbls Comments: LRS hot oil unit Do not exceed 1135 psi with diesel CD2 -76 Ann LOT 2012 -07 -15 Summary II • _ i • . _.„....... r.. • ...,--,..,:. ._. ( 14i4. „v4i1,, ti<ii iiiieiV4i..iidti6t s• fAii:OS i..i.biii 1-.bitt.344. .. *4=041 tiro..:pet0011, as itill dt:.,4hereledn up, Ilulat'xesa 7-.49p4n7 out .t. i'l:,.t.46. »Iat iill';- 0:t 00 165iiiiifiiitiii figa tiievlauly b.ePt-Wiiad dj*Ziiii4•:' 4, ii6i 13k6ail ll'i li up 1 '-:0ifft - iiteia'atill.3.A di:S' ' 1 . -xt - cal_ 'd•-• tit;:.e6 'las.v..!:1. Z1 osAi.opaons :P. , . •:::- -:: Iite*i 145311.345•/. :P4ideeSSOY A:10. bjaa- 1:■3;ibliib tigi Ilietaaii- , ... 14•40,441. I.:, • 400* 0 * 00.144kwor44toi5ogwoww4,44-4#041404to1 as # .., . W .pacteal arid *nrirotitrit4Sip,14:0tnAtiVe ..,..... .. . . ,. „.. . .41t. regues.tithe ae rio thferrtt ifla,P, Pxemlous1y.1.450 4 ... ,., .' )0,kii0 .i09:T- of *9:1;;P 4.T.r.oppool#J.44:44:a 'o., Al-.P40.4 •:itlig:'4E6iiiiilAigii6iii:Axa:AW ifie's i'd .:WS,::' . 6g 1 , '..,6fit - _ • !, ... ..... cbtlalEg VfillaEpt It:Ld.xxtboxImed to ispos II.I.ildh. Irv. Mt: ASg i" , • - . .. , g00*.,41:t 10,.....-i,...iifl.'1*•:.•aiA404.. . . - 1j41.041iiiag#, T..., . 1 466 • ' ":- . '7.. ' ... '.. - - ::::::::::::::: *•' 4 .*4e::.jistt..tia.:Aed 4r0.;:'K;Ansion.?::,pz;91.TuSiy.:..rewest.s.d! . .. .. ...>,..,...u.chorl...katp..: ;dispose. of •new,cr.goduct,..cIsan up g c.ement. . . „., ,.. .., '4144.-'4cux,•.. 1:94: x.)..qap.....%i=rom..mix-In ppc.ra...xpAp :.a nnu1ar . .: .....-". , k. :. '4.7..• : .,..:'''...-.. P.,51.19.,t,■.7, ,:;:•,..,'..! Q.,.1*. ' :.7.-,..." - -- - s -;,-'.,.. , . - r:A ,, . ''' • gj ........- ..... l .:r 1 14,9,0 ' l in :,.? 1 ' 1 6,.. .4 , .g. q. ,-ptP4IRMA..",.q.p.ix prt,..w„. g.r.e% :... .p •*? O.PP.04..4:!Pl*.#::: 4 .:.*0!: Site 'i.'-ir;:.j.,•0•00,,,::.be0 .: iiitiO'ilj' i6ra iikiiigab: de' the iitieiiiiAliWlaill4. iriCMlie.:'cji•i:s.j:1`e dAlIii4 , .oper.dtaiork..,: - . :;$-q#1.40•01 4-4.4:Aggiighg .4.-,?:: :54goggs.:.44, i..0.1.0,4%.: , *• tan] .4#ig:61Aosit;i4.4eiw Jt*4Wi 41#. ::fisaka'iii..44$6 Ok'adij&a.ii.V•41543.S' 4 0'" Ilig.=Edna.ii &40 dq 'and' :;,..,:.,.-04,43tailabinity,::ottairitizig garpiri.Ot?tdoil,,:#i-:::1.4.:::diTx.:0-3?.44.1.4 at , ?: V44 W ;01*1:t1:4 *'-;#040--4.10-440:97444.,PPggl...;40.0$41.1.4*4 4 . ,-,, 'ciiagfil:Et4:;ilOti. £l :O .1 ;d40ii ' 4 1 440..4:0).0: ' # . 1%. 1 4 4tqg'#§4A* - ::s.4 - giub - oiwifita - " " " " - • • . ' — . - .. .• • .• - ---- ' — -- ' - ' - • . . ::..: 0 the intti4n.t4n %, t Ini,cg. ... !,. ,..>i ou11 ',.„-v,4..12.. ,,s PC Pi944q.t.4).44:i;41-44'. (60, szt4:40:07:4 *.,0,00 O ,i41 :1,-,:qr*A2tt. ';::; A•0:p,4 /111.g. a•A44.,1.: g:444:0).. .*'. fht • * OtPiii*4'.*I g .a ' ''''' WVi*xy to pr.4p*343F.e.,t,, ,.. s".44'406ii1 Oiii69.:, 4Aiiaai'Al'it56 iiiti management - e- ....... , ..'...-,ii . i.E.rnaill . me inA,h444:3case,., .' • ( . • • • . • 1111.411X 1 0-t 933Pe •e ao ox ny &1orgAtw**)..e14411.. t,9-437J qp-.4200 mogq..:73,0. (g9g1 ,AMP EAVYLOOid .,„ „ , To affd66 ubject Reauest to Ibteeti..tement:Rinsae: CD2 . - ttg:*44..:*441, r?1 (O00) of OW AP*10:1A b,g, Pt&I) 'he ppG al as aita to • Wit ).4154 ..411qP.': id 44Wggz:e1 Y0.1:.0.0.s. up to " ''''' • '"" ggliA4g4PRFP*931 NTA4 • '00 "a(A Kntiche4 44g444:4t. to • the fliaa PPZ). g: f tcl...4410:;'.d§:7 at • 2NIPAh • 1,0 RECEIVED PRESSURE INTEGRITY TEST JUL 2 0 2012 CONOCOPHILLIPS Alaska, Inc. Well Name: CD2 -76 Rig: Little Red Date: I 7/15/2012 _ I Volume Input AOGCC Pump Rate: Drilling Supervisor: 1 D. Mickey 'Pump used: Other - See Comments v i Barrels ■ Bbls /Strk ♦ Bbl /min l ir 1 Type of Test: Annulus Leak Off Test for Disposal Adequacy ♦ Pumping down annulus and DP. ■ Casing Test Pressure Integrity Test Hole Size: 9 - 7/8" v 5 Casing Shoe Depth Hole Depth Pumping Shut -in Pumping Shut -in RKB -CHF:I IFt 3382.6IFt -MD( 2386.4IFt- TVD 3413.0IFt -MD 12398.1(Ft -TVD Bbls psi Min I psi Bbls psi Min psi Casing Size and Description: 10 -3/4" 45.5 # /Ft L -80 BTC v 0 0 0 0 500 0 990 Changes for Annular Adequacy Test Pressure IntegrityTest 2 110 1 0.5 505 1 930 Enter outer casing shoe te: 9.7 in comments Mud Weight: 6.8 ppg 4 270 2 1 540 2 920 Casing description referee 51.0 casing string. Inner casing OD: 40.0 In. 6 430 3 1.5 570 3 900 Hole Size is that drilled bel 3530.0 casing. 124000.0 8 625 4 2 610 4 900 Use estimated TOC for He 124000.0 74000.0 10 800 5 2.5 650 5 890 Enter inner casing OC 74000.0 Desired PIT EMW: 15.5 ppg 12 910 6 3 720 6 880 Estimates for Test: 1080 psi -21.9 bbl 14 1010 7 3.5 790 7 880 v v 16 1125 8 4 830 8 865 EMW = Leak -off Pressure + Mud Weight = 1060 + 6 8 PIT 15 Second 18 1240 9 4.5 860 9 860 0.052 x TVD 0.052 x 2386 Shut -in Pressure, psi 20 1375 10 5 930 10 860 EMW at 3382.62 Ft -MD (23 Ft -TVD) = 15.3 930 22 1495 15 5.5 970 15 830 1500 -- 24 1625 20 6 1020 20 820 26 1760 25 6.5 1060 25 800 -- ■ 28 1900 30 7 1020 30 790 == ..= � 30 2050 7.5 1020 �� 32 2200 8 1020 _ ■�� 34 2360 8.5 1000 - - - - -- w 1000 _� ∎�� 36 2525 9 1000 — - - i 38 2690 9.5 990 ct � ■•■••■■■ ��∎ 40 2850 10 990 L ��C =�� 42 3025 W �� 44 3200 - - - -- a — 500 �� ∎�∎ 4468 48 3360 3530 ��1� ■•111111=11111■••1111M1111■ - - -iii -- -- = -- 0 - 0 1 2 3 4 5 6 7 8 9 10 0 5 10 15 20 25 30 Barrels Shut In time, Minutes Volume Volume Volume Volume amill■CASING TEST —FLEAK -OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 48.0 Bbls IBbls 10.0 Bbls JBbls Comments: LRS hot oil unit Do not exceed 1135 psi with diesel V / CD2 -76 Ann LOT 2012 -07 -15 Summary • • Note to File CRU CD2 -76 (PTD 2090980) July 20, 2012 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD2 -76 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus surrounding the 7 -5/8" casing within Colville River Unit well CD2 -76. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 10 -3/4" surface casing shoe is set in this well at 3,382' measured depth (- 2,343' true vertical depth subsea, or "TVDSS "), near the base of a 420 -foot thick shale and claystone interval that persists throughout the area. This interval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of sandy siltstone open to the surrounding the 7 -5/8" casing within this well to accept the proposed injected fluids. 3. The lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights are protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities should be limited to a radius of about 120' from the wellbore. Discussion CPAI's application was reviewed along with records from nearby wells Alpine 1A, CD2 -33A, CD2 -72, and CD2 -465. An index map is provided in Figure 1, below. Drilling wastes will be disposed in an open annulus that extends downward from the10 -3/4" surface casing shoe, which is set at 3,382' measured depth (- 2,343' TVDSS), to the top of cement for the 7 -5/8" casing string, which is estimated to lie at about 4,716' measured depth ( -2868' TVDSS). This annulus spans the boundaries of Section 2 of Tl 1N, R4E, UM and Section 35 of T12N, R4E, UM (see Figure 1), and it lies more than 6 -1/2 miles from the current exterior boundary of the Colville River Unit. The section of open annulus that will most likely accept the injected waste fluids (most likely receptor interval) is a 140 -foot thick portion of the Seabee formation that extends from 3,550' to 3,910' measured depth (- 2,410' and - 2,550' TVDSS; see Figure 2, below). This interval contains several 1- to 3 -foot thick beds of sandy siltstone that are interbedded with clay and claystone. The aggregate thickness of the sandy siltstone beds is about 18'. • • CD2 -76 July 20, 2012 Note to File Page 2 of 6 CD2 -76 CD2-465 C ` .,\ CRU CD2 -76 CD2 -72 Annulus Area of Review ' ./ x ) , Alpine ♦ 4 • • A1 f C P F - Alpine 1A CD2 -33A ♦, ♦ ♦ ♦♦ Surface Casing Shoe (/" // A y �. Figure 1. Index Map (CRU CD2 -76 open annulus highlighted with yellow; cross - section path highlighted with magenta) The 10 -3/4" surface casing shoe lies near the base of a 420 -foot thick interval that is dominated by shale and claystone (see Figures 2 and 3, below). This interval is continuous throughout the area, and it will provide upper confinement for the disposed fluids. Beneath the most likely receptor interval is a 60 -foot thick interval of claystone and mudstone that is also continuous throughout the area. This interval, which lies between 3,910' and 4,068' measured depth (- 2,551' and - 2,613' TVDSS), will provide lower confinement for injected. Other, laterally continuous intervals of claystone and mudstone also underlie the receptor interval and will provide additional lower confinement. In vicinity of Drill Site CD2, the base of permafrost occurs at about - 1,250' TVDSS, which is about 1,160' above the top of the most likely receptor interval. Conclusion 3 of Area Injection Order 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. Alpine lA is the nearest exploratory well to Drill Site CD2. In Alpine 1A, methane was first encountered at 760' measured depth (about -700' TVDSS), and it was encountered in significant quantities (more than 1% methane in air, or 50 units) at 1,155' measured depth (about - 1,075' TVDSS). So, the entire proposed disposal zone likely contains some methane gas. The shallowest oil shows encountered in Alpine 1 A were two trace shows observed between 2,985' and 3,380' measured depth (from - 2,208' to - 2,358' TVDSS). However, the descriptions of these shows note a lack of oil staining; the shows were noted based on sample and solvent cut fluorescence. The shallowest record of visible oil staining occurs at about 4,630' measured depth (- 2,819' TVDSS), which is 350 true vertical feet below the likely receptor beds for the injected material. So, at Drill Site CD2, the likely disposal interval does not contain potentially commercial hydrocarbons. • • CD2 -76 July 20, 2012 Note to File Page 3 of 6 corr.nt.m [h Resn roresry UtINA) .140 ReaIXRW) " 12 QN.1A1 200 WC, 254 ■ SPINA) TV055> ResM(RFt) 100 7.x o■ns+ OR i3O ResS(RV5) 10 AC, 241 11 070Aa 20C_ VN <MD 177C,,,, 170 Ot SR(NA1 1000 3300 Surface casing shoe Upper 00 — Confining .. Strata 3500 MO IIE 3600 Most Like. Receptor 3700 Interval fora Disposed Fluids . 4`` 3800 1 1 it_ L. 3900 Lower Confining 4000 Strata 4100 2700 4200 4300 voo 4400 4500 ,1 4600 t ---- 2900 ■ 4700 4600 � .. 4900 5000 .._ Figure 2. CD2 -76 Well Log for Affected Intervals • • 1 CD2 -76 July 20, 2012 Note to File Page 4 of 6 2011240 2070570 2090980 2081450 501032038101 501032054600 501032060300 501032058300 E L W 4 1463ft 4 167 ft 4 1478ft ■ ■ CONOCOPHILLIPSALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK CONOCOPHILLIPS ALASK COLVILLE RIV UNIT CD2 -33A COLVILLE RIV UNIT CD2-72 COLVILLE RIV UNIT CD2 -76 COLVILLE RIV UNIT CD2 -465 1894 FNL 1522 FEL 2208 FNL 1984 FEL 2217 FNL 2063 FEL 2190 FNL 1845 FEL TWP: 11 N - Range: 4 E - Sec. 2 TWP: 11 N - Range: 4 E - Sec. 2 TWP• 11 N - Range: 4 E - Sec. 2 TWP: 11 N - Range: 4 E - Sec. 2 ==ii= 1500 1°' ' . .. - - - - 1500 « Base Permafrost 1000 " v � ,m , M _ 1000 500 :: .: --'4" l i 500 Upper - A 9 -5/8 casing shoe Confining - _ a Most Likely N Strata 0 - - ° Receptor - 0 m _ Interval for i i _ Disposed Fluids r w -500 _ Lower _ 506 t Confining / ? Strata a ' -1000 r. 1 -1000 ® TD =15355 TD=20189 TD•23855 TD =13733 Figure 3. Stratigraphic Cross - section from CRU CD2 -33A to CRU CD2 -465 The chart presented in Figure 4, below, provides an estimate of the subsurface volume around CD2 -76 that will be affected by the proposed annular disposal operations. There are about 18' of porous sandy siltstone beds within the most likely receptor interval, according to a count using the gamma ray curve from CD2 -76. Inspection of the porosity well logs obtained in CD2 -76 suggests an average porosity of about 30% for the sandy siltstone beds within the most likely receptor interval. Based on these values, and assuming piston -like displacement of native formation fluids, the proposed annular injection operations should directly affect the receptor beds only to a radius of about 120' from the wellbore, as indicated by Figure 4. Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains methane gas, is situated beneath about 1,250' of permafrost, and is bounded above and below by continuous layers of shale and claystone. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the most likely receptor interval beneath CD2 -Pad. The • • CD2 -76 July 20, 2012 Note to File Page 5 of 6 Injected Fluid vs Affected Radial Distance CD2 -76 Wellbore (assumes 18' aggregate injection zone thickness and 30% porosity) 200 - — 1 180 160 .a 140 m £ 120 0 2 100 a 80 co c 60 CD w 40 - w w Q 20 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 4. Radial Distance Potentially Impacted by CD2 -76 Injection I -6000 - 5000 pop\ 0000 2500 - 40007000 -4000 550:`• -4500 6500 -3000 A -4000 3500 -3500 - 4000 C RU CD2 -76 -4snn Area of Review Annul - 2500 - 3500 30 -3000 7000 -. 3000 At 02000 550II - - -- r 2500 2500 -- 3500 3500 500 „ 3000 - 20i -2000 " -00 k1 n 2000 3000 P.50. ` 200C -6500 1500 -1500 - =3500 -6000 -550D / , , 2000 _6000 _5000 0G odnn 4500 j ' 65 40tG / A Surface Casing Shoe :'''' «r 500 251 r 0 - 4000 \) 00' -400 ,w �;. 2500 t 400 -2500 -4500 3500 5000 "4500 -3000. 45 a r .. 0 6503 350 0 4,490 -6000 2000 Figure 5. Index Map - Enlarged (CRU CD2 -76 open annulus highlighted with yellow; cross - section path highlighted with magenta) • • CD2 -76 July 20, 2012 Note to File Page 6 of 6 open annulus proposed for disposal injection lies inside the Colville River Unit, well away from any external property lines, so correlative rights are not a concern. I recom •• a approval of this annular disposal project. _ _7 ZC) - /2.— Steve Davies Senior Petroleum Geologist • Note to File CD2 -76 (PTD 209098 Sundry 312 -265) Colville River Unit (Qannik) ConocoPhillips Alaska, Inc (CPAI) ConocoPhillips has made application to authorize a 35,000 bbl annular disposal in the subject well. This document examines the pertinent information for the well and recommends approval of CPAI's request. -- No unusual events were reported while drilling the surface hole of the well (CD2 -76). -- 10 -3/4" Surface casing was cemented to surface successfully. No problems were reported. Approximately 139 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 145% XS of the calculated hole volume. -- On the initial leak off test (LOT) for the surface casing shoe dated 10/24/2009, the pressure slope rises smoothly to -16.6 EMW and continues at a slightly shallower slope to 18.0 EMW. Minimal fluid was pumped in. The pressure declined slightly during the observation period to about 15.6 ppg EMW. The initial leak off indicates that the surface casing shoe is well cemented. -- Intermediate hole experienced losses and the 7 -5/8" ,casing was run and stuck 3704 ft off bottom. The intermediate casing was cemented in 2 stages, with a AOGCC calculated TOC at 5026 ft MD (30% excess and 95% effic.) on the 2 stage. CPAI has recalculated their TOC as 5097 ft MD (40% excess and 95% effic.). Qannik zone was covered in the second stage (44bbls) of the cement job. 10 -3/4" casing shoe is 3383 ft MD. - -The most recent injectivity test down 10 -3/4" x 7 -5/8" annulus was conducted on 7/15/2012. Pressure steadily increases until the break at 13.8 ppg EMW, then continues to 15.3 ppg EMW before declining to a final 14.8 ppg EMW. During the observation period, the pressure declined to 13.2 ppg EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. - -There are multiple wells (15) wells within '/ mile radius of CD2 -76. The surface shoe of CD2 -09 is closest, about 573' distant. CD2 -72 is 700', and CD2 -02 is 751' distant. AD was recommended for CD2 -09 in 2004. CD2 -72 had annular disposal of 26,500 bbl ending 2008, and CD2 -02 has not had annular disposal. Evaluation of these three wells cementing information and additional reviews of the pad wells surface casing cementing records did not reveal anything to preclude granting CPAI's request. G: \tommaunder \Well Information\By Subject\Annular Disposal \120719_CD2 -76 AD request.doc • As provided in 20 AAC 25.080 (b) (15), CPAI has provided information on their current well inventory status, schedule, well identification and decision process, and future disposal plans and options. CD1 pad wells were evaluated for annular injection operations and rejected for various factors relating to high injection pressures and wellbore integrity. Class I well CD1- 19A is currently non - operational and in need of a workover, and CRU WD -02 is deemed critical to the successful continuation of the project (sanitary waste disposal) and is at risk of being compromised by the injection of the high solids drilling waste streams. Other wells were evaluated and rejected based on overall project risk, operational status, workover risk, production impacts, and schedule impact. As provided in 20 AAC 25.080 (d) (4), after review of the information provided to demonstrate that compliance with the same drill pad generation and disposal of waste limitation is imprudent, I recommend that the commission determine to authorize disposal of drilling waste through the annular space of a well (CD2 -76) not located on the same drill pad as the drilling operation generating the drilling waste (wells CD1 -22B, CD1 -01, and CD1 -47). Based on examination of the submitted information, I recommend approval of CPAI's request for the subject well. Due to the close proximity, CPAI should monitor the outer annulus pressures on CD2 -09 while pumping on CD2 -76. Chris Wallace Sr. Petroleum Engineer AOGCC July 23, 2012 G: \tommaunder \Well Information\By Subject\Annular Disposal \120719_CD2 -76 AD request.doc • • PM 201 O g Wallace, Chris D (DOA) From: Dai, Weifeng [ Weifeng.Dai @conocophillips.com] Sent: Friday, July 20, 2012 10:15 AM To: Wallace, Chris D (DOA) C J ,��-_ ,S )''7 - :4012- Cc: Kanady, Randall B; Schwartz, Guy L (DOA); Stinson, Rob D Subject: RE: Annular Disposal request for Offsite pad disposal on CD2 -76 (PTD 2090980) Chris, Thanks a lot for the help to expedite the approval of CD2 -468 permit. I apologize for the discrepency of TOC on different documents and appreicate you point them out. I double checked and please refer to my answer below. 1. The estimated TOC for primary cement job of 7 -5/8" casing is 11,707' MD(40% excess volume), the estimated TOC for second stage job is 5,097' MD(40% excess volume. The return volume during cement job is 95% of total pumped volume according to DDR, so I multiply 0.95 in calc too). 2. To be more conservative and safer,this time I pick the highest pressure and calculate the EMW LOT is 15.3# now. I will rescale the volume to l Obbls and submit updated plot this morning. ----- Please add CD1 -47 well in the well list for contingency. ,/ Weifeng Alpine Drilling Engineer, CoP Alaska ATO 1704 Office: (907)- 263 -4324 Cell phone:(907)- 538 -4125 From: Wallace, Chris D (DOA) [ mailto :chris.wallace @alaska.gov] Sent: Thursday, July 19, 2012 5:07 PM To: Dai, Weifeng Cc: Kanady, Randall B; Schwartz, Guy L (DOA); Stinson, Rob D Subject: [EXTERNAL]Annular Disposal request for Offsite pad disposal on CD2 -76 (PTD 2090980) Weifeng, We have received the CD2 -76 application and are progressing it, CD2 -468 is approved and ready for courier pickup as advised to Randy this afternoon. Can you please provide additional details of: 1. Operator evaluation of the cement zonal isolation coverage for the intermediate casing. With the 2 stage cement job, can you please identify the TOC for each stage. E.g. for the 2n stage I see different TOC mentioned from the daily reports (4729 ft MD) vs. wellbore diagrams provided with the application (TOC 5067 ft MD) vs. AOGCC spreadsheet calculations (4716 ft MD gauge hole, 4984 ft MD 30% excess calc). 2. For the injectivity test dated 7/15/2012 and referenced in the application as 13.8 ppg EMW LOT, please resubmit with smaller (10 bbl) scale and please confirm your evaluation is 13.8 ppg EMW. Please also confirm if you wish me to add on well CD1 -47 (as per CD2 -468 application) to include for your contingency? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 • • Rob Stinson Supervising Drilling Engineer P.O. Box 100360 Anchorage, AK 99510 :onocoPh l l s rob.d 263 @ @ @9 (phone) rob .d.stinson @conocophillips.com July 18, 2012 Hand Delivered Commissioner Daniel T. Seamount, Jr., Chairman RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 JUL 1 8 2012 Anchorage, AK 99501 AOGCC Subject: Supplemental Information Application for Annular Disposal of Drilling Waste on well CD2 -468 and CD2 -76 Request to move Muds and Cutting from CD1 to CD2 Dear Chairman Seamount: ConocoPhillips Alaska has recently submitted annular disposal applications on wells CD2 -468 and CD2 -76. This letter provides supplemental information on the subject applications and justification for taking drilling muds and cuttings from CD1 to CD2 for annular injection. • For the current drilling program on CD1, CD1 -15 was identified as the well that CPA was going to use for annular disposal of muds and cutting. Initial injectivity testing on this well showed that it could be a viable candidate. However when CPA rigged up on CD1 -15 for annular disposal, annular injection could not be established with an injection pressure at the maximum allowable shoe pressure. This resulted in a detailed annular injection evaluation for all the available wells on CD1. Annular injection has not been utilized on CD1 since 2004. CD1 -15 and CD1 -48 are the most recent wells drilled and completed on CD1 after 2004, however annular injection could not be established on these wells. Attachment 1 is an annular injection summary spreadsheet which was used to evaluate annular injection candidates on CD1. This spreadsheet summarizes the annular injection volumes on CD1 by well and calculates the surface casing shoe separation from the current well CPA is drilling (CD1 -22) and the distance to other surface casing shoe on CD1 pad. This spreadsheet was used to identify which CD1 wells additional injectivity tests would be conducted on. The two key criteria utilized when choosing candidate wells for the test was: 1. The surface casing shoe is at least 500' away from CD1 -22 surface casing shoe, which is the well will be drilled. 2. The initial surface casing shoe LOT is at least 0.5 pound higher than the annular LOT equivalent mud weight. • • • Base on the criteria, the wells chosen and tested were: CD1-21 CD1-30 CD1-39 CD1 -18 CD1 -07 CD1 -38 CD1 -26 CD1 -25 CD1 -30 CD1 -04 CD1 -23 CD1 -45 CD1 -34 CD1 -16 CD1 -42 CD1 -12 CD1 -05 CD1 -40 CD1 -14 CD1 -03 CD1 -37 CD1 -44 CD1 -48 CD1 -31 CD1 -09 Injectivity tests were conducted so that the maximum allowable surface casing shoe pressure would not be exceeded. Unfortunately, none of the tests show good injection behavior. Attachment II is a few representative injectivity test plots for reference. Since no annular injection wells were found on CD1. CPA reviewed annular injection wells on CD2. Both CD2 -468 and CD2 -76 where found to have good annular injectivity. As a result CPA is requesting permission from AOGCC to haul muds and cutting from CD1 to CD2 for annular disposal for the interim period until our new Class injection well, CD1 -01A is sidetracked and completed. CPA plans to finish the well Doyon 19 is currently drilling CD1 -22A. The next well planned is a side track on CD1 -01A and is being proposed as a new Class 1 injection well for CD1. Once CD1 -01A is completed and permitted as a Class 1 disposal well CPA will use this well as our primary muds and cutting disposal well and we will not have to move muds and cuttings from CD1 to CD2 for annular disposal. CD1 -19A is the Class 1 disposal well that has been used on CD1 for muds and cutting disposal. Unfortunately the tubing was recently compromised between the straddle packers set a crossed the Alpine sands. Plans to fix CD1 -19a are being reviewed. These plans have been complicated recently by a wireline fish in the well. WD -02 is a Class 1 injection well located on the Alpine pad. CPA relies on this well for injecting /disposing treated waste water and other Class 1 fluids from Alpine Operations. Alpine is a zero discharge facility and does not have an NPDES permit to discharge treated waste water. As a result CPA does not want to put solids down WD -02 and risk plugging this well off. This has been the standard for Alpine operations ever since WD -02 was drilled. If you have any questions regarding this supplemental information, please contact me at 263 -4449 or Weifeng Dai, Senior Engineer at 263 -4324. Sincerely, i Rob Stinson Supervising Drilling Engineer SURFACE CASING SHOE SEPARATION FROM CD1 -22 CD1 -22 X Y Surface Casing Shoe ASP 4 Coordinates: 385890.63 5975753.63 uistance from Surface csg. Details @ Ann Vol Object Surface csg. Shoe Y Surface Surface Wells AOGCC Permit # Permit Date (bbls) End Date well* Shoe X Coord. Coord. TVD FIT /LOT Ann LOT Comments CD1 -01 y 339 -116 7/12/1999 383 386000.88 5976120.23 2364 15 15.4 Not a candidate CD1 -02 y 626 386406.59 5976107.32 2398 16 16.7 Not a candidate, questionable surface casing FIT CD1 -03 y 300 -005 1/13/2000 870 385744.09 5976611.32 2370 15.8 15.1 Test failed CD1 -04 y 1232 386800.96 5976584.44 2377 15.7 13.9 Test failed CD1 -05 y 300 -022 1/27/2000 926 386752.76 5976091.39 2387 16 15 Test failed CD1 -06 y 1404 387261.90 5976054.67 3090 16 15.7 Not a candidate CD1 -07 y 304 -047 2/19/2004 1494 387324.34 5975332.78 2362 16.9 13.2 Test failed CD1 -08 y 304 -382 11/1/2004 2123 387783.06 5974790.61 2343 16.2 15.3 Test failed CD1 -09 y 300 -163 6/22/2004 1540 387400.42 5976058.56 2790 15.99 13.7 Test failed • CD1 -10 y 322 386080.76 5976013.75 2403 15.9 15.7 Not a candidate CD1 -11 2025 387540.43 5974579.42 2363 18.1 15.6 Test failed CD1 -12 1557 387039.60 5974702.41 2347 15.2 13.8 Test failed CD1 -13 y 399 -121 7/19/1999 457 386333.24 5975867.57 2387 15.6 15.6 Not a candidate CD1 -14 2240 388120.50 5975539.11 2366 16 15.1 Test failed CD1 -15 y 1449 387230.46 5976306.05 2394 16.6 14.6 Permitted, but fail to inject CD1 -16 y 399 -213 11/2/1999 805 386666.50 5975539.37 2399 15.9 14.2 Test failed CD1 -17 y 536 386386.08 5975549.67 2385 15.24 16 2000 well CD1 -18 y 1030 386303.66 5974809.97 2354 18 15.2 Test failed CD1 -19 y 399 -064 4/20/1999 1157 386182.40 5976873.16 2393 14.6 Class I Disposal Well CD1 -20 y 1457 386803.35 5974618.03 18 15.7 Test failed CD1 -21 y 304 -009 1/12/2004 32000 1123 385033.54 5976479.08 2391 16 14.8 Test failed CD1 -22 y 0 385890.63 5975753.64 3110 CD1 -23 y 399 -141 8/5/1999 1625 387499.21 5975525.36 2398 13.6 N/A Test failed CD1 -24 1124 387001.62 5975585.79 2390 13.4 11.9 Not a candidate due to low FIT CD1 -25 y 300 -102 4/17/2000 33587 1108 386816.46 5975145.40 2398 16 14.8 Test failed CD1 -26 y 996 386511.26 5974974.98 2389 15.9 14.5 Test failed CD1 -27 y 300 -058 3/22/2000 972 386148.85 5974816.28 2366 16 15.2 Not a candidate due to communication between IA and OA CD1 -28 y 111 385780.25 5975747.82 2372 16 15.7 Not a candidate CD1 -229 y 1887 386239.91 5973899.61 2385 15.6 14.5 Test failed CD1 -30 y 1162 384814.85 5976193.13 2387 16 14.8 Test failed CD1 -31 y 300 -263 848 385054.61 5975893.22 2378 15.2 14.5 Test failed CD1 -32 y 399 -245 1138 384754.69 5975829.24 2413 15.2 15.5 Not a candidate CD1 -33 y 138 385796.34 5975652.73 2430 15.8 16.3 Not a candidate CD1 -34 y 300 -133 5/8/2000 378 505 385543.31 5975386.66 2361 16 14.2 Test failed • CD1 -35 y 399 -086 5/21/1999 317 270 385634.65 5975667.79 2388 15.7 16.7 Not a candidate CD1 -36 y 399 -260 1/3/2000 713 385189.14 5975626.47 2406 15.3 15.5 Notacandidate CD1 -37 y 399 -162 8/27/1999 32587 1120 385828.32 5974635.64 2409 15.5 15.1 Test failed CD1 -38 y 300 -051 2/29/2000 1287 385516.01 5974522.02 2376 16.1 15.6 Test failed CD1 -39 y 399 -181 9/10/1999 861 385568.87 5974954.54 2388 15.5 15.1 Test failed CD1 -40 y 399 -101 6/11/1999 1654 385005.59 5974356.58 2392 16 15.4 Test failed CD1 -41 y 300 -104 4/24/2000 707 385231.03 5975499.87 2394 15.2 15.4 Not a candidate CD1-42 y 399 -261 1/3/2000 1364 384596.37 5975321.88 2384 15.3 14.7 Test failed CD1-43 y 300 -241 9/20/2000 1428 384753.45 5974889.55 2386 16 16 Not a candidate CD1-44 y 300 -146 5/31/2000 31928 2115 384506.22 5974155.17 2375 15.5 14.8 Test failed CD1-45 y 299 -233 11/17/1999 1351 384726.63 5975067.43 2385 16 14.2 Test failed CD1-46 y 304 -381 10/22/2004 1663 385970.99 5974092.50 2362 15.5 15.3 Not a candidate CD1 -48 y 1857 385856.15 5973896.95 2396 15.40 14.20 Test failed Lateral distance in feet, between surface casing shoes, in the X -Y plane Note that this sheet is not the definitive record. PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD1-21 Rig: Little Red 'Date: I 7/13/2012 I Volume Input Pump Rate: Drilling Supervisor: ,1 D. Mickey 'Pump used: other - See Comments vr Barrels Mr 1 i 1 Bb ! ls/Strk 1 4I 0.50, Bbl/min , Ir I , ! ■ Type of Test: 1Annulus Leak Off Test for Disposal Adequacy i Illr Pumping down annulus. ■ Ily , . ,.... Casing Test Pressure Integrity Test Hole Size: , 9 i v Casing Shoe Depth 1 Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF:1 LFt 2718.01Ft-MD1 2379.0IFt-TVD 8376.0IFt-MD I 6724.0 [Ft-TVD Bbls psi Min psi Bbis psi Min psi Casing Size and Description: 1 9 36#/Ft 3 Bit No' 0 0 810 0.00 1110 Changes for Annular Ade 1..._A.Itemm 1 0.5 850 0.25 1100 Enter outer casing shoe test results in comments Mud Weight: 6.7 ppg 2 1 920 0.50 1080 Casing description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 1020 1.00 1060 Hole Size is that drilled below outer casing. 4 2 1060 1.50 1040 Use estimated TOC for Hole Depth. 5 2.5 1100 2.00 1010 Enter inner casing OD at right. Desired PIT EMW: 15.5 ppg 6 3 1110 2.50 1000 Estimates for Test: 1089 psi 1.5 bbls 7 3.5 1138 3.00 990 1 ' ■ ` ' 8 . 3.50 980 EMW = Leak-off Pressure+ Mud Weight = 1138 "-- + 6 - PIT 15 Second 9 4.00 970 .7 0.052 x TVD 0.052 x 2379 Shut-in Pressure,psi 10 4.50 970 EMW at 2718 Ft-MD (2379 Ft-TVD) = 15.9 1100 15 5.00 970 1500 20 5.50 970 _ _ _ ....... . ___ _ _ ____ _ _ - 25 6.00 97 _ _ _ __ _ 30 6.50 970 7,00 970 7.50 970 lop° it.......eee.. •* 11---111-- ----1111.---1111 - 8.00 970 8.50 970 Lu ec . 9.00 970 u) 9.50 970 c.r) 10.00 970 • IX 500 _ _ _ 0 0 1 2 4 5 6 0 5 10 16 20 25 39 Barrels Shut-In time, Minutes Volume Volume Volume Volume 'amillrom CASING TEST - II - LEAK - OFF TEST 0 PIT Point Pumped Bled Back Pum 4 ed Bled Back 0.0 BbIs Bbls 3.6 13bIs Bbis omments: 9 :" casin• s oe - = • .0 ppg Do not exceed 1138 •si with diesel UM - Annular LOT Of-13-1'L Summary . . PRESSURE INTEGRITY CONOCOPHILLIPS Alaska, Inc. | | 'Date: Well Name: � CD1'34 ��q Little |�m�m� � 7;3/2012 1 Volume Input Pu Rate: 1 'Pump ' | Drilling Supervisor: |_ -_____- HeoHan±�g used: a | �� ouu�� 1r / O . 5 Bbl/min Type of Test Annulus Leak Off Test for Dsposa Adequacy / 'V Pumping down annulus. 1 1 0 � Casing Test / | Integrity Test �--- | Pressure - ^ Hole Size: m�/r /`� Casing Shoe Depth Hmle Depth Shut-in Pumping Shut-in IFt 2,433 2 D | 6784 Ft�VD Bb|a U psi Min psi Bb� psi Min psi Casing Size 9 36#/Ft |`� U D 0 840 0 1160 ' Chan �es�r Annular PrmmmuwmVntwg�tvTwmt 1 0.5 860 1 1180 outer casing shoe test results in comments Mud Weight: 6.8 ppg 2 1 880 2 1160 ' Deseription references outer casing string. Inner casing 00: 7.0 In. 3 1.5 900 3 1180 3izeia that drilled below outer casing. 4 2 930 4 1155 . idmotedTDC for Hole Depth. 5 2.5 960 5 1155 Enter inner casing 00 at right Desired PIT EMVV: 15.5 ppg 6 3 990 6 1155 Estimates for Test: 10 0 psi 0.8 hblm 7 3.5 1040 7 1155 8 4 1080 8 1155 -� | |nr �kQu� G�� --- 9 4.5 114O O 1155 ---'-''' '----'- ''—='- + � 8 0�5�z�� Q�5�� 3G� — t�mPrwsmmmm,psi 10 4.G 11GO 10 1155 ��N��a��kQ@U��-��K� 1�.� | 1160 15 5.5 15 1150 1500 - --------- 20 6 20 1150 - i - - ' 25 6.5 25 1145 ---' 30 7 30 1140 7.5 `-- -----'1--�' 8 8 mo ------------ Iii ~ - _ ` -_--__ __-_-____'__- 9.5 �- --' - - ----�-----�------- ------------ 1O um -- '- '-------� --- ' -' Y�- ---------- ' - -[-'- Et ____--' _-___________-� ___ ~~ ___-. � -___'� '_- _ I em' -------'------------ --'- --- --- ' - ---- ----' -- _- __-_--'____-_______ _ _________ . _ '_ ��`�`�� `� ' -___�____-____-__- _---_ _____ __''____ 0 0 2 6 8 10 12 14 16 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume ~..dr..'CAS/we — III — LEAK - OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 0.0 Bblm Bb|s 10'0 Bb|e BbXs Comments: 9 5/8 casing shoe LOT =16.0EmW - -- -- - --' LRS hot oil unit Do not exceed 1160 psi with diesel �� . , PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD1-48 Rig: No rig on well I:12a:te: I 7/16/2012 1 Volume Input i Pump Rate: — , r Drilling Supervisor: D. Mickey Pump used I Other - See Comments Niv L._ 1 . Barrels 1 lir I Bbls/Strk 1/ 0.5i Bbl/min I llr . I I Type of Test: Annulus Leak Off Test for Disposal Adequacy V' 1 Pumping down ; annulus. IP' — I , Casing Test Pressure Integrity Test i Hole Size: 8 ■ • Casing Shoe Depth L Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 1Ft 3,160 1Ft-MD1 2,3961Ft-TVD 3,1901Ft-MD 1 2,4111Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9 36#/Ft 3-55 BTC I – . 0 0 560 0 1090 Chanties for Annular Adequacy Test Pressure IntegrityTest 1 0.1 660 1 1080 suter casing shoe test results in comments Mud Weight: 6.8 ppg 2 0.2 740 2 1075 Description references outer casing string. Inner casing OD: & In. 3 0.3 840 3 1070 • ize is that drilled below outer casing. 4 0.4 940 4 1070 .timated TOC for Hole Depth. 5 0.5 1090 5 1070 Enter inner casing OD at right Desired PIT EMW: 15.5 ppg 6 6 1070 Estimates for Test: 1084 psi ####### 7 7 1065 , .., ' ■ . 8 8 1060 EMW = Leak-off Pressure + Mud Weight = 860 +68 PIT 15 Second 9 9 1060 . 0.052 x TVD 0.052 x 2396 Shut-in Pressure, psi 10 10 1060 EMW at 3160 Ft-MD (2396 Ft-TVD) = 13.7 1080 15 15 1500 . . 20 20 _ . - 1000 w 500 ce m co 0 Ui EX ---- _ ' 2 25 - 30 a. • - - --- -- . 0 0 1 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume Volume Volume Volume ..1.011•CASING TEST -41—•LEAK-OFF TEST 0 PIT Point Pumped Bled Back Pum ied Bled Back 0.0 Bbls Bbls 0.5 abls Bbls Comments: Used Little • ed's Hot •il ruck for pumping Diesel Original 9 5/8" shoe LOT = 15.4 ppg Do not exceed 1090 psi with diesel ATE OF ALASKA ALASKA OIL ANdirkS CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other 17 Scale Inhibition Alter Casing Rill Tubing Perforate New Pool Waiver Treatment A g � 9 � r r Time Extension �""" Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development j Exploratory r _ 209 - 098 3. Address: 6. API Number: 1- Stratigraphic 1 — Service P. O. Box 100360, Anchorage, Alaska 99510 00 7. Property Designation.(Lease Number): r 8. Well Name and Number: ADL 387212, 387211, 025530, 380095, 380075 FEE A-SRC-) /1 11 0 CD2 -76 9. Field /Pool(s): Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 15769 feet Plugs (measured) none true vertical 7298 feet Junk (measured) none Effective Depth measured 15769 feet Packer (measured) 12383 true vertical 7298 feet (true vertucal) 5942 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3346 10.75 3383 2387 INTERMEDIATE 12807 7.625 12841 6116 LINER 3384 4.5 15767 7297 r RECEIVED r'r NOV 1 0 2011 Perforation depth: Measured depth: 15498' - 15538' 41-'` 5 4 s' " j True Ver Depth: 718T- 7198' kh"3z .�.) ' Alaska 01i & Gas Cans, COtrmissieti Antorap Tubing (size, grade, MD, and TVD) 3.5, L - 80, 12434 MD, 5962 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 'HRD' ZXP Liner Top packer @ 12383 MD and 5942 TVD SSSV - CAMCO TRM- 4PE /CF @ 2221 MD and 1925 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 15498' - 15538' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 152 1149 329 -- 239 Subsequent to operation 202 1507 423 -- . 244 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development Service r Stratigraphic r 15. Well Status after work: 4 .. Oil (✓ Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Dan Kolesar 2.;, -4039 Printed Name Dan Kolesar f Title WNS Production Engineer Signature % a , Phone: 263 -4039 Date (f ' p p ` ( / a —..- 1 RSOMS Nov 1 fat "o fir. P ' 4" Form 10 -404 Revised 10/2010 Submit Original Only "ite • • Scale Inhibition Treatment CD2 -76, 10/21/2011: Scale Inhibition Treatment: Initial pressure TBG /IA /OA- 230/1150/440; Facility pumped 50 bbls SW preflush; LRS pumped 0.5 bbls WAW5206 (20 gal) at 2.6 bpm and facility pumped 5 bbls SW, 400/1085/460; LRS pumped 5 bbls SCW3001WC (200 gal) at 2.4 bpm and facility pumped 27 bbls of SW, 2700/1110/475; LRS pumped 0.5 bbls WAW5206 (20 gal) at 2.6 bpm and facility pumped 5 bbls SW, 2700/1110/475; facility pumped 248 bbls of SW over - displacement I IONS 0 CD2 -76 At Cone oPhIIh . ps $ Well Attributes Max Angle & MD TD a Wel!bore APUUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (11KB) Alaski3. lrif. , t, ,,,, rzPixiGPS T 501032060300 ALPINE PROD 69.94 12734.20 15 769.0 - TRDP Annotation End Date ‘KB - Grd (ft) Rig R Date SSSV E Daten) last WO' 43 87 12/2/2009 - _ Well Gontl9: HOR¢QN' . .eQ,g ti i,W2 ,_ __, ___ Annotation A(il,.� - Scd1erF.!.7 @AC11a`:L { d ... End Date Last Tag- SLM l De � h ( ftKB) nd 15,500.0 1 12/24/2010 j Last Mo Annotation Rev Reason' GLV C/O ninam 1 4/30/2011 (ANC -R. 31 - CC asing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... ( String Wt... String ... String Top Thrd J ,i; CONDUCTOR 16 14.688 37 0 114.0 114.0 109.00 H-40 Welded Insulated 24" Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ", _ .. _. SURFACE 10 3/4 9.950 36 5 3,382.6 2,386.5 45.50 L BTC m Do Casing Description String 0... String ID ... Top (ftKB) Set Depth (f -.. Set t Depth (TVD) ... String WI... String ... String Top Thrd I INTERMEDIATE 75/8 6.875 34 - 1 12,840.7 6,115.5 29.70 L BTCM Casing Description String 0... String ID ... Top (ftKB) Sat Depth .. (f. Depth (TVD) ... String Wt... String ... String Top Thrd "CONDUCTOR LINER 41/2 3.958 12,383.0 15767 - 1 7 4 1260 L SLHT Insulated 24 - - Liner Details 37 -114 _._._ Top Depth _..- ...' (TVD) Top Ind Nomi... Tom • B (MB) 1") Item pace•/'n Comment ID (in) .. 12,383.0 5,942.0 66.54 PACKER Baker "HRD" ZXP Liner top packer - 5 - 12 x 7 - 5/8" (6.55" OD x 4.95" ID) 4.950 li SAFETY VLV, I 12,402.0 5,949.6 66.59 NIPPLE "RS° Packof Seal Nipple -5 -12 (6.06" OD x 4.875" ID) 4.875 x 2.221 12,404.8 5, 950.7 66.59 HANGER Baker Flex- lock hoer hanger 5-1/2"x 75/8 "(6.6" OD x 4 -83" ID) 4.830 12,414.2 5,954.4 66.61 XO BUSHING 5.5 x 5" crossover bushing (6.05" OD x 4.42" ID) 4.420 • 12,417.3 5,955.7 66.62 SBE Baker 5" 80-40 Seal bore extension (5.02" OD x 4.0" ID) 4.000 12,435.8 5,962.8 66.59 XO BUSHING 5" x 4.5" crossover bushing (5 56" OD x 3.92" ID) 3.920 Tubing Strings Tubing Description String 0 !String ID Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... (String .. Stang Top Thrd TUBING 4.5x3.5 3 1/2 I 2.992 31.2 I 12,434 4 I 5,962 3 9.30 I L-80 I EUE -m SURFACE,____ 1 Completion Details 363,383 ° Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftB) C) Item Description Comment ID (in) � 31.2 31.2 -0.03 HANGER FMC Tubing Hanger (11" x 4 -12 ") 3.958 2,221.4 1,925.2 59.25 SAFETY VLV 4-1/2" Camco TRM- 4PE /CF SSSV w/ 3.813" DB profile 3.812 2,281.2 1,955.0 61.51 X0 - Reducing 4.5" 12 68 L -80 IBTM crossover to 3.5" 9.36 L -80 EUE 3.500 12,311.0 5,914.2 67.25 NIPPLE Camco 3 -1/2" DS Nipple (2.813" min ID) (Bore 2.812") 2.813 12,415.6 5,955.0 66.62 LOCATOR LOCATOR 2.990 rat 12,422.9 5,957.9 66.63 SEAL ASSY BakerGBH -22 8040 Bonded Seal assembly 3.000 GAS L 7 Perforations & Slots Shot Top (TI/D) Btm(TVD) • Dens Top (ftKB) Btrn (am, (ftKB) (ftKB) Zone Date (h _ Type Comment 15,498 15,518 7,182.7 7,190.3 4/11 /2011 I 6.0 APERF 2.5" GUN, 60 degree phase GAS LIFT. _.. _ -. " 15,498 15,538 7,182.7 7,198.2 12/20/2009 6 0 IPERF 2.5" MILLENIUM, 60 degree phase 11,534 15,5181 15.5381 7,190 -3 7,198.2 4/10/2011 6.0 RPERF 1 2 5" GUN, 60 degree phase ( • __. _._ __ Notes: General & Safety End Date Annotation 12/3/2009 NOTE Well was originally named CD2-176, changed to CD2 76 when dolling zone changed GAS 12 UFT, � ,282 ___ _ _ 12/3/2009 NOTE VIEW SCHEMATIC w /Alaska Schemat c9 0 IIM - - - - _ - - -- NIPPLE, 12,311 -- 1� � LOCATOR, 12,416 r :. .,.:: TUBING SPACER,-. __ 1 • 3 8 12,417 SFAL ASSY, _ 12,423 -- IMO s.�...U:P..14!. '•T "" ' . '.. - ",-- - . 3 '3f- - -4 , 3461 , ..., 3 . '0 32Y 2Y 8`c 3 ` , •rep „„e., NTERMEDIATE,� Top Depth Top £ P L 34- 12,841 (TVD) Ind OD Valve Latch Size TRO Run APERF, Stn Top Mk MKS) (9 Make Model (in) Sere TyPe TYP• (In) (pai) Run Date Corn... 15888- 15,516 IPERF, 1 5 3,420.4 68.29 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 12/1/2009 1s15,498.15,538 -- • '.. 2 11,534.4 5,606.3 67.60 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,779.0 4/28/2011 __ RPERF, �- �� 15,518 - 15,538 .... 3 12,262.0 5,895.5 67.49 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 4/17/2011 ,7 LINER, 12,383 - 15,767 -- - - - - -- TD (CO2 -76), 15,769 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 5, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: CD2 -76 Run Date: 4/10/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2 -76 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20603 -00 / (/j -'Id 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 Klinton Wood @halliburton.com Date: Signed: O , � i I I g II ?\- - o�� STATE OF ALASKA ALASKA", AND GAS CONSERVATION COMMIS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other r Alter Casing r Rill Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate P Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r - 209 -098 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 103 20603 - 00'"' 0 0 7. Property Designation (Lease Number,: 8. Well Name and Number: ADL 387212, 387211, 025530, 3800'35, 380075 - CD2 -76 9. Field /Pool(s): Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 15769 feet Plugs (measured) None true vertical 7298 feet Junk (measured) None Effective Depth measured 15769 feet Packer (measured) 12383 true vertical 7298 feet (true vertucal) 5942 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3346 10.75 3383 2387 INTERMEDIATE 12807 7.625" 12841 6119 LINER 3384 4.5" 15767 7297 MA\:' 0 a zuy4 RECEIVED' Perforation depth: Measured depth: 15498' 15538' _ 't.) . ; l i 'I'i True Vertical Depth: 7183' -7198' Alaska Gil & Gas Cons. 6onxrnsSN1A Tubing (size, grade, MD, and TVD) 3.5, L -80, 12434 MD, 5955 TVD r i1CTIQUitge Packers & SSSV (type, MD, and TVD) PACKER - BAKER 'HRD' ZXP LINER TOP PACKER @ 12383' MD, 5942' TVD SAFETY VLV - 4 - 1/2" Camco TRM 4PE /CF SSSV @ 2221 MD and 1925 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 43 2063 2 -- 257 Subsequent to operation 270 403 979 -- 275 13. Attachments 14. Well Class after work: .. Copies of Logs and Surveys run Exploratory r Development � �ll' '. Service r Stratigraphic r 15. Well Status after work: _Oil P' Gas r WDSPL r Daily Report of Well Operations XXXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 310 -400 Contact Tim Schneider (a) 265 -6859 Printed Name Tim Schneider Title Staff Production Engineer Signature Phone: 265 -6859 Date // i j i - 1 --C --- RBDMS APR 28 2Oh1 Form 10-404 Revised 10/2010 S,Z.4 Submit Original Only CD2 -76 Well Work Summary DATE SUMMARY 2/24/11 GATHER EQUIPMENT AND PREOE FOR PERFO/ TRACTOR STROKER At MOBILIZE TO ALPINE. 2/27/11 TEMPERATURE /PRESSURE SURVEY FROM SUFACE TO 3100'. 10MIN STOP CHECKS@ 3100, 2750, 2100, 1700, 1500, 1472, 1200 ,1050,850,650,350,250,150,100, AND 0. 2/28/11 ATTEMPT TO PERFORATE FROM 15,518- 15,538' W /20' 2.5 "OD 11GRAM MILLENIUM CHARGES 6SPF,60DEG PHASING. TOOLS WOULD NOT FALL BELOW 15,115' AFTER SEVERAL ATTEMPTS.WILL ATTEMPT 10' GUNS TOMORROW. JOB IN PROGRESS 3/1/11 ATTEMPT TO PERFORATE 15,498- 15,538' TOOLS WOULD NOT FALL PAST 15,115'. ATTEMPTED SHORTER 10' GUN RATHER THAN ORIGINAL 20' GUN, ALSO INSTALLED 2.75" ROLLER ON BOTTOM OF GUN. NO PROBLEMS FALLING UNTIL BRIDGE OUT @15,115' TOOLS DID NOT STICK/PULL OVERPULL OFF OF BRIDGE. 3/27/11 TBG OPEN 2.85" TO 12311' RKB, SET 2.85" STANDING VLV @ SAME, PULLED 1" GLV @ 11534' RKB, ATTEMPT TO PULL OV @ 12262' RKB, IN PROGRESS. 3/28/11 REPLACED 1" OV @ 12262' RKB W/ DV. SET 1" DMY VLV @ 11534' RKB. MIT TBG TO 2500 PSI. PULLED STANDING VLV @ 12311' RKB BUT HANG UP @ 12250' SLM, SHEARING GR, IN PROGRESS. 3/29/11 MAKE SEVERAL ATTEMPT TO PULL STANDING VLV @ 12258' SLM, RAN 2.75" LIB TO STANDING VLV @ 12258' SLM LIB SHOWS CLEAN FN. IN PROGRESS. 4/6/11 LATCHED CAT STANDING VALVE AT 12244 CTMD, PULLED 12K OVER, 1 -JAR HIT, POOH WITH FISH. WELL IS FREEZE PROTECTED. READY FOR E -LINE. 4/10/11 RAN WELLTEC TRACTOR AND HES PERFORATING GUN 2 1/2" 60 DEG , 6 SPF, MILLENIUM. RE- PERFORATE 15518 - 15538'. TRACTOR THRU MULTIPLE BRIDGES FROM 15100 - 15210'. TOOLS STOPPED AT 15425'. MADE MULTIPLE ATTEMPTS TO GET DEEPER. PUMPED DOWN TUBING WITH LRS ASSIST @ .75 BBLS @ 3850 PSI. REACHED DEPTH OF 15608'. PUMPED REMAINING DIESEL (55 BBLS) ABORD TRUCK DOWNHOLE. 4/11/11 RUN IN HOLE WITH HES PERFORATING GUN 2 1/2" 60 DEG , 6 SPF, MILLENIUM AND RE- PERFORATE THE FOLLOWING INTERVAL: 15498 - 15518'. BEGIN FUNCTION TEST ON THE TRACTOR FOR THE KICKOVER TOOL. CONTINUE JOB IN THE MORNING. 4/12/11 RUN IN HOLE WITH WELL TEC TRACTOR AND GLV SERVICING TOOLS. AFTER REACHING THE GLM @ 12262' NUMEROUS ATTEMPTS WERE MADE TO PULL THRU GLV AND ENGAGE THE LOCATOR ON THE TOOL. WE WERE NOT ABLE TO GET THE LOCATOR TO LATCH IN THE GLV. PULL OUT OF HOLE TO FIND METAL DEBRIS HAD BEEN WEDGED ALONG SIDE OF THE KICK OUT TOOL. RUN OUT OF HOLE WITH TRACTOR AND TRY AGAIN ON NEXT DAY. 4/12/11 BRUSHED & FLUSHED TBG TO 12,275' SLM. READY FOR ELINE. 4/13/11 RUN IN HOLE WITH WELL TEC TRACTOR AND KICK OVER TOOL TO LATCH THE DMY VALVE IN GAS LIFT MANDREL @ 12262' / PULL INTO GLM WITH KICK OVER TOOL / LOCATE AND LATCH THE DMY VALVE / WELL TEC ENGAGE ANCHORS AND PULL DMY VALVE THEN PULL OUT OF HOLE / RUN BACK IN HOLE WITH 1/4" SO GLV WITH BK LATCH / MAKE MULTIPLE ATTEMPTS TO LOCATE IN THE GLM WITH NO SUCCESS / PULL OUT OF HOLE / 4/17/11 SET 1/4" OV @ 12262' RKB. COMPLETE 4 • WNS CD2 -76 - Phillips a \ Well Attributes Max Angie & MD TD Wollbore APUUWI Feld Name Well Stets Ind(*) MD (ftKB) Act Btm (ftKB) 501032060300 i ALPINE PROD 69.94 12,734.20 15,7690 Comment H2S (ppm) (Date Annotation End Date KB-Grd (ft) Rig Release Date Well Contig MOR¢0NTAL CD2 76, 4/102011 ' 26:38 PM SSSV TRDP 1 Last WO - 43.87 12/22009 Schematc Actual_ Annotation h (ftKB) End D t Annotation Last Mod... End Date Last Tag: SLM l Dept 15,500.0 l 12/24/2010 Rev Reason: PERFORATIONS, GLV C/O lmosbor 4/18/2011 H 3. 4 ' Strings ANGE 31 - , -. _.. Casin. Strin s " Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wl... String ... String Top Thrd �' ) , - - CONDUCTOR 16 14.688 37.0 114.0 114.0 109.00 H-40 Welded Insulated 24" i Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd - - - - SURFACE 10 3/4 9.950 36.5 3,382.6 2,386.5 45.50 L -80 BTC -m - -- - ---' �. F: Casing Description n String 0... String ID ... Top (ffK8) Set Depth (i... Set Depth (ND)... String Wt... String... String Top Thrd INTERMEDIATE 75/8 6.875 34.1 12,840.7 6,115.5 29.70 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 LINER , 1/2 3.958 12383 0 15,767.1 7,297 4 12.60 L - SLHT CONDUCTOR • - Insulaled24•, . Liner Details _' 37 -114 " __- Top Depth Nomi... , . To p MKS) OWN 1.1 Item Description Comment ID (in) 12,383.0 5,942.0 66.54 PACKER Baker ZXP Liner top packer - 5-1/2" x 7 -5/8" (6.55" OD x 4.95' ID) 4.950 OF SAFETY VLV, _ 12,402.0 5,949 6 66.59 NIPPLE "RS" Packoff Seal Nipple- 5-1/2" (6.06" OD x 4.875" ID) 4.875 2,221 12,404.8 5,950.7 66.59 HANGER Baker Flex- lock liner hanger- 5 -12" x 75/8 "(6.6" OD x 4.83" ID) 4.830 12 414.2 5,954A 66.61 XO BUSHING 5.5" x 5" crossover bushing (6.05" OD x 4.42" ID) 4.420 12,417.3 5,955 7 66.62 SBE Baker 5" 80-40 Seal bore extension (5.02" OD x 4.0" ID) 4.000 12,435.8 5,962.8 66.59 XO BUSHING 5" x 4. 5" crossover bushing (5 56" OD x 3 92" ID) 3. 920 iI Tubing Strings Tubing Description ;Strin 0._ String ID ... Top (1166) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrd TUBING 4.5" @ 31 3 1/2 2.992 31 2 12,434 4 5,962.3 9.30 L -80 EUE -m SURFACE. x 3.5" @ 2281 1 38 -3,383 .' Completion Details Top Depth 1 (TVD) Top Inc! Nomi... Top (kK8) (ftKB1 ...- ('1 Item Descri . non Comment ID (in) 31.2 31.2 -0.03 HANGER FMC Tubing Hanger (11 "x 4 -12") 3.958 2,221.4 1,925.2 59.25 SAFETY VLV 4-1/2" Camco TRM- 4PE /CF SSSV w/ 3.813" DB profile 3.812 II 1 2,281.2 1,955.0 61.51 XO - Reducing 4.5" 12.6# L -80 IBTM crossover to 3.5" 9.3# LAO EUE 3.500 • 12,311.0 5,914 -2 67.25 NIPPLE Camco 3-1/2" DS Nipple (2.813" min ID) (Bore 2.812') 2.813 12,415.6 5,9950 66.62 LOCATOR LOCATOR 2.990 ME 12,422.9 5,95/.'9 66 63 SEAL ASSY BakerGBH -22 80 -40 Bonded Seal assembly 3.000 GAS LIFT. ( - -- 5,937 OK Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB (kK8) (ftKB) Zone Date (sh••• I Type Comment GAS LIFT, u:.. 15,498.0 15,518.0 7,182.7 7,190.3 4/11/2011 6.0 APERF 2.5" GUN, 60 degree phase 17534 'a' 15,498.0 15,538.0 7,182.7 7,198.2 12/20/2009 6.0 IPERF 2.5" MILLENIUM, 60 degree phase 15,518.0 15,5320,. 7,190.3 7,198.2 4/10/2011 6.0 RPERF 2 5" GUN, 60 degree phase Notes: General & Safety End Date Annotation 12/3/2009 GJO Well was originally named CD2 -176; changed to CD2-76 when tlrilfing zone changed 12/3/2009 NOTE: VIEW SCHEMATIC wlAlaska Schematic9. 0 NIPPLE, 12,311 -- - - hi LOCATOR -_ -... -. _.... '.1: c 12,416 C TUBING ' ' SPACER, 12,417 SEAL ASSY, 12,423 ICI NTERMEDLATE, Top Depth Top Port 3412841 • (ND) Incl OD Valve Latch Si.. TRO Run APERF, Stn (k (% Make Model On) Sery TSP. TSP. (tn) (Pe9 Run Date Com... 15,498- 15,516 IPERF, - 1 5,936.6 3,420.4 68.29 Camco KBMG 1 GAS LIFT DMY BK - 5 0.000 0.0 12/1/2009 15,496 RPERF, 2 11,534.4 5,606.3 67.60 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/28/2011 15,518 - 75,536 - - 3 12,262.0 5,895.5 67.49 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 4/172011 LINER, 1 12,383- 15,767 TD (CD2 76), 15,769 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED April 01, 2011 „ 0 4 7 re0 ftsks ail 8 lies Cam$. C o Mission Commissioner Dan Seamount Anchorage Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 f 0 Anchorage, AK 99501 s , $ p,PR 4� 8 2°1r �� 1- Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor . • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 04/01/2011 CD2 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD2 -14 50103203900000 2011770 4" n/a 16" n/a 5.4 3/14/2011 CD2 -16 50103204260000 2021440 4" n/a 14" n/a 3.6 3/14/2011 CD2 -17A 50103204060100 2051700 4" n/a 14" n/a 3.6 3/14/2011 CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 CD2 -26 50103203970000 2012320 4" n/a 16" n/a 2.7 3/27/2011 CD2 -33B 50103203810200 2011250 4" n/a 15" n/a 2.7 3/27/2011 CD2 -41 50103204240000 2021260 4" n/a 14" n/a 4.3 3/28/2011 CD2 -50 50103204150000 2020490 8" n/a 16" n/a 3.5 3/27/2011 CD2 -51 50103204410000 2022490 510" 0.80 15" 3/21/2007 3.9 3/27/2011 CD2 -56 50103204980000 2041500 SF n/a 15" n/a 3.8 3/27/2011 CD2 -58 50103204570000 2030850 6" n/a 6" n/a 3.5 3/28/2011 CD2 -59 50103205050000 2042480 6" n/a 6" n/a 5 3/27/2011 CD2 -60A 50103205110100 2091150 6" n/a 6" n/a 5.25 3/27/2011 CD2 -74 50103205910000 2081970 10'9" 1.20 9" 3/26/2011 1.7 3/27/2011 CD2 -76 50103206030000 2090980 32" n/a 32" n/a 9.7 3/27/2011 CD2 -78 50103206010000 2090660 6" n/a 6" n/a 1.7 3/27/2011 CD2 466 50103205760000 2080950 8" n/a 17" n/a 3.4 3/27/2011 • Page 1 of 1 Regg, James B (DOA) 2Og — O f g From: NSK Problem Well Supv [n1617 @conocophillips.com] G ' r �� i � Sent: Saturday, March 12, 2011 4:41 PM l To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; ALP DS Lead and Simops Coord Subject: CD2 -76 (PTD 209 -098) Report of IA SCP Attachments: CD2 -76 schematic.pdf Tom, Jim, Guy Alpine gas lifted producer CD2 -76 (PTD 209 -098) was reported with SCP on the IA. Currently the well is SI and has been since 07/19/10. There is a suspected sand bridge in the tubing so the current pressure is unavailable. The current IA and OA pressures are 2221/353. A leaking GLV is suspected. Slickline will troubleshoot the GLV's and repair if possible or secure the well with a tubing tail plug. Attached is a 90 day TIO plot and schematic Please let me know if you have any questions. -- /54 ( , Z9.7 4 Brent Rogers /Martin Walters Problem Wells Supervisor SCE = c-ZzI ps ConocoPhillips Alaska, Inc. " Desk Phone (907) 659 -7224 til P 6 ` � tors; z' Z.(14, Pager (907) 659 -7000 pgr. 909 h rtt i *e cvifi le— 4 • Pe- Co 4q5" 3/15/2011 CRU CD2 -76 PTD 2090980 3/12/2011 TIO Pressures Plot TRN_ANNL ANNULUS PRESSURE TRENDS TPH_PNIL_INIT 500. CC WELL NAME WLALPCD2 -76 3000. 3000 200. 3000. 3000. 2700 3000. nn(' 2400 3000. h • 2100 =�kr * s 18D0 7 1 . 'son - - - 4 1 1200 900 • D . . -.. 600 4 0. r`\ .gH -M-H 0. 300 I r 0. 0. 0 — -__i n I,: 0. PLOT START TIME MINOR TIME PLOT DURATION PLOT _ aID Tin, .. 12- DEC -10 16:15 MAJOR TIME WEEK 441i. I ,:. _; NRS 1 *tU ' 1 III PICK TINE 12-MAR-11 10:27:42 E 8W 3M IS 111111/11 CM - ,C TAG NAME DESCRIPTION e Visi.G±: TEST Fler CD2 MHIC 312103 -P -076 FLOW TUBING CHOKE 7777777 DRILLSITE WELL PIW SCRATCH 86 FLOW TUBING PRESSURE 7777777 PREV WELL cd2 76 pmw SCRATCH_86 FLOW TUBING TEMP 7777777 NEXT WELL Pwr CD2- PI- 302112A -076 GL CASING PRESSURE 7777777 7777777 ENTRY TYPE OPERATOR par 7777777 PAW OPERATOR VERIFIED SCRATCH_06 INNER ANNULUS PRES 7777777 I1 SYSTEM AUTO ENTRY Fliff SCRATCH_06 OUTER ANNULUS PRES ?? ? ? ? ?? MI BOTH WNS CD2-76 Cono illips 5 } ; '' Wen At butes - „ii T I4 i i I` ' 1111 r1 (f Wellbore API /UWI Field Name Well Status Incl () MO (ftKB) Act Btm (RKB) 501032060300 ALPINE PROD 69.94 12,734.20 15,769.0 Comment 1125 (ppm) Date Annotation End Date KB -[irtl (ft) Rig Releaae Date :WeB Coo HORIZONTAL- CD276, t2125l01o951.23 AM SSSV: TRDP Last W0: 43.87 12/2/2009 gcbemeW ,93tuel Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 15,500.0 12/24/2010 Rev Reason: TAG Imosbor 12/25/2010 HANGER, 31 r Ga81nq vStrtllg8 ° .h . .. ' z+ . T- si s + Casing Dounption String 0... String ID ... Top (ftKB) Set Depth (C.. Set Depth (TVD) ... String Wt... String ... String Top Thrd -- - -- } -- CONDUCTOR 16 14.688 37.0 114.0 114.0 109.00 H -00 Welded Insulated 24" 1 Casing Description String 0.., String ID .. TOP (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .., String Top Thrd g _ SURFACE 103/4 9.950 36.5 3,382.6 2,386.5 45.50 L - 80 BTC - m ^, Coning Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ,_ ; 1 INTERMEDIATE 75/8 6.875 34.1 12,840.7 6,115.5 29.70 L - 80 BTCM r - Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (WD( ... String Wt... String ... String Top Thrd LINER 4 1/2 3.958 12,383.0 15,767.1 7,297.4 12 60 L SLHT CONDUCTOR {a 1 ( Insulated 24" ° Lin ' _ ?e# ila _ x , re,.. 37 -11a �,,,.,, 4� ,4' Top Depth Nomi... ITVD) Top Incl ID (1n t RKB) Comment (in) B ( Item Descn Ion M PI ) 12,383.0 5,942.0 66.54 PACKER Baker "HRD" ZXP Liner top packer- 5 -1/2" x 7-5/8" (6.55" OD x 4.95" ID) 4.950 12,402.0 5,949.6 66.59 NIPPLE "RS" Packoff Seal Nipple -5 -12" (6.06" OD x 4.875" ID) 4.875 SAFETY VLV, 2,221 12,404.8 5,950.7 66.59 HANGER Baker Flex- lock liner hanger- 5 -1/2" x 7- 5/8 "(6.6" OD x 4.83" ID) 4.830 12,414.2 5,954.4 66.61 X0 BUSHING 5.5" x 5" crossover bushing (6.05" OD x 4.42" ID) 4.420 it 12,417.3 5,955.7 66,62 SBE Baker 5" 80-40 Seal bore extension (5.02" OD x 4.0" ID) 4.000 12,435.8 5,962.8 66.59 X0 BUSHING 5" x 4 5" crossover bushing (5.56" OD x 3.92" ID) 3.920 9 Tubmg D ac IpBOn Stnng O.. String ID ... Top (RKB) Set D pth (f... Set D pth (7 /0) ... St ing Wt... String ... String Top Thrd TUBING 4.5 @ 31.2 3 1/2 2.992 31.2 12,434.4 5,962.3 9 30 L-80 EUE -m x35" @2281' SURFACE, ` ♦ 36.3.383 Top Depth (TVD) Top Incl Nomi... Top (RKB) (ftKB) ( °) Item Description Comment ID (in) 31.2 31.2 -0.03 HANGER FMC Tubing Hanger (11 "x4-12 ") 3.958 2,221.4 1,925.2 59.25 SAFETY VLV 4-1/2" Camco TRM- 4PE /CF SSSV w/ 3.813" DB profile 3.812 2,281.2 1,955.0 61.51 X0 - Reducing 4.5" 12.6# L -80 IBTM crossover to 3.5" 9.3# L -80 EUE 3.500 12,311.0 5,914.2 67,25 NIPPLE Camco 3 -12" DS Nipple (2.813" min ID) (Bore 2.812 ") 2.813 12,415.6 5,955.0 66.62 LOCATOR LOCATOR 2.990 12,422.9 5,957.9 66.63 SEAL ASSY BakerGBH -22 80 -40 Bonded Seal assembly 3.000 GAS LIFT. .y� S� 5.937 s:: Perforations & SIotS - .} -,'�: - . s'.�_ =F igi Shot Top (TVD) Btm IND) Dena T op ( RKB ) Btm (RKB) (RKB) (RKB) Zone Date I.h... Type Comment art k' 15,498.0 15,538.0 7,182.7 7,198.2 12/20/2009 6.0 IPERF 2.5" MILLENIUM, 60 degree phase GAS LIFT. _ - �, _ li S 11,534 : == Notes: general & Safety P .. `I- � L, iF End Date Annotation 12/3/2009 NOTE: Well was originally named CD2 -176; changed to CD2 -76 when drilling zone changed 12/3/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT. 12,262 itat NIPPLE, 12,311 JET h1 1II LOCATOR. 12,416 r TUBING 1 SPACER, 12,417 SEAL ASSY, i 12.423 1T. N T MaridretDetalls = " = ' r - m }, Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run NTERMEDIATE Stn 7op (RKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (Pall Run Date Com... 34 12'x41 1 5,936.6 3,420.4 68.29 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 12/1/2009 IPERF, 2 11,534.4 5,606.3 67.60 Camco KBMG 1 GAS LIFT GLV BK 0.125 1,634.0 12/25/2009 15,49e 15.538 ''',ft - - 3 12,262.0 5,895.5 67,49 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 6/13/2010 LINER, • i 12.383- 15.767 TD (CD2.76). 15,769 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 2, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Pressure - Temperature Survey: CD2 -76 Run Date: 2/27/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2 -76 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20603 -00 SIANNEV Ma 1 6 zo PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 069 �(4 Fax: 907 - 273 -3535 rafael.barre ut?, ED 7 Date: Signed: _ DATA SUBMITTAL COMPLIANCE REPORT 1/13/2011 Permit to Drill 2090980 Well Name /No. COLVILLE RIV UNIT CD2 -76 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20603 -00 -00 MD 15769 TVD 7298 Completion Date 12/2/2009 Completion Status 1 -OIL Current Status 1 -OIL REQUIRED INFORMATION �� Mud Log No Samples No Directional Sury -Al DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint III Well Log Information: Log/ Electr D Digital Dataset Log Log Run Interval OH / pe Med /Frmt Number /Name Scale Media No Start Stop CH Received Comments ED C 19151 Induction /Resistivity 3355 15769 Open 1/13/2010 EWR logs in CGM and TIFF graphics with PB1 and PB2 Togs o Induction /Resistivity 25 Col 114 15769 Open 1/13/2010 M LD ROP, DGR, EWR, i g Induction /Resistivity 25 Col 114 15769 Open 1/13/2010 TVD ROP, DGR, EWR, ALD, CTN d Log Induction /Resistivity 25 Col 114 16548 Open 1/13/2010 PB1 MD ROP, DGR, EWR, ALD, CTN Log Induction /Resistivity 25 Col 114 16548 Open 1/13/2010 PB1 TVD ROP, DGR, EWR, ALD, CTN .14 Induction /Resistivity 25 Col 114 13348 Open 1/13/2010 PB2 MD ROP, DGR, EWR, ALD, CTN • og Induction /Resistivity 25 Col 114 13348 Open 1/13/2010 PB2 TVD ROP, DGR, EWR, ALD, CTN D C Las 19259+ Perforation 15271 15573 Case 1/26/2010 Perf, Tens, GR, CCL Rpt Directional Survey ✓ 36 15769 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 1/13/2011 Permit to Drill 2090980 Well Name /No. COLVILLE RIV UNIT CD2 -76 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20603 -00 -00 MD 15769 TVD 7298 Completion Date 12/2/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N ADDITIONAL INFORMATION Well Cored? Y it) Daily History Received? 0- Chips Received? i-N— Formation Tops 41I N AnalysisF-P- Received? • Comments: Compliance Reviewed By: Date: l 3 Ov_ K.C) • 0 • T 'clifkij y [ / SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 X (907)276 279 - - W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 7) FAPHONE 7542 1433 Tim Schneider WNS Staff Engineer ConocoPhillips Alaska, Inc. Q�� P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -76 Sundry Number: 310 -401 Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 Daniel T. Seamount, Jr. Chair pp- 7 DATED this C.. day of December, 2010. Encl. STATE OF ALASKA ALAS•IL AND GAS CONSERVATION COMMIS * i� �` � .� APPLICATION FOR SUNDRY APPROVALS : ;:d;'"):' Z l '"I '� 20 AAC 25.280 1. Type of Request: Abandon J"'" Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate ' Rill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r c fi rs- -f Stimulate I✓', , Alter casing ?NtC Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 209 - 098 ` 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20603 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 17 CD2 - 9. Property Designation (Lease Number): , 10. Field / Pool(s): ADL 387212, 387211, 025530, 380095 _ C . Colville River Field / Alpine Oil Pool - 11. < . % PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15769 - 7298 • 15769' 7298' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3346 10.75 3383' 2387' INTERMEDIATE 12807 7.625 12841' 6119' LINER 3384 4.5 15767' 7297' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 15498'- 15538' 7165 4.5 / 3.5 L -80 12434 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) BAKER HRD ZXP PACKER MD= 12383 TVD= 5942 SAFETY VLV - 4 -1/2" Camco TRM- 4PE /CF SSSV MD= 2221 TVD= 1925 12. Attachments: Description Summary of Proposal ' 13. Well Class after proposed work: Detailed Operations Program fl BOP Sketch Exploratory Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/20/2010 Oil , Gas r WDSPL E Suspended 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r i. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider © 265 -6859 Printed Name Tim Schneider Title: WNS Staff Engineer Signature ��C% Phone: 265 -6859 Date pee, 6, 20 /0• Commission Use Only r� Sundry Number: `j' 0 — Conditions of approval: Notify Commission so that a representative may witness ✓✓ �/ �l Plug Integrity r BOP Test fl Mechanical Integrity Test r Location Clearance RECEIVED Other: DEC 0 7 2010 Subsequent Form Required: / 0' 1 041 _ = ilaSka Old & ties tsQn.Q. COrIM1MS31 ®n Anchorage f / APPROVED BY 1 / Approved by: Date : / / COMMISSIONER THE COMMISSION � neAC nor ` Form 10 -41 - - = i @ 'I/209'0 0 11 I �z 7 /. Submit In Duplic r� ORIGINAL /2-7/t0 . . i. L '''' • WNS CD2-76 Iv Conoco Phillips .4 Well Attributes Max Angle & AfaSK0, kV. Wel Wore APWLIWI Field Name Well Status Ind r) , IMD WKS) Act Ben (ftKB) 501032060300 ALPINE PROD 69.94 12,734.20 15 769.0 - Comment r (ppm) Date Annotation TRDP J End Date KB.Grd (ft) Rig Release Date ... SSSV. well C55 HORIZONTAL - C72-76, 0220/20 0 6 07 13 Alt ..,----- - Last WO' _ ___- 43.87 12/2/2009 mat Scheic Aclual ' Annotation i Depth (f ti71:TilEnd Date 'Annotation Last Mod ... End Date Last Tag CTMD I 15,680.0 9/9/2010 Rev Reason: TAG Imosbor 10/8/2010 1569069, 31 Casing Strings 1 Casing Description • String 0... 'String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 14.688 37.0 114.0 114.0 109.00 H-40 Welded Insulated 24" Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (1VD) ... String Wt... String ... Siting Top Thrd SURFACE 10 3/4 9.950 36.5 3,382.6 2,386.5 45.50 L BTC Cwing Description -- String 0... String ID Top (ftKB) Set Depth Depth (TVD) ... String Wt... String ... String Top Thrd 111 : , INTERMEDIATE 75/8 6.875 34.1 12,840.7 6,115.5 29.70 L BTCM Casing Description String 0... String ID ... Top (fWB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 41/2 3.958 12,3830 15,767.1 7,297.4 12.60 L SLHT CONDUCTOR Insulated 24 Liner Details 37-114 - Top Depth 1 (TVD) Top Inc! Notes.. III, Top (ftKB) (MB) ('1 Item Description Comment ID (in) 12,383.0 5,942.0 66 54 PACKER Baker "HRO" ZXP Liner top packer-5-1/2" x 7-5/8" (6.55" OD x 4.95" ID) 4 950 It 12402.0 5,949.6 66.59 NIPPLE "RS" Packoff Seal Nipple-5-1/2" (6.06" OD x4.875" ID) 4.875 SAFETY VLV, - = - 2,221 " 12,404.8 5,950.7 66.59 HANGER Baker Flex- lock liner hanger- 5-1/2" x 7-5/816.6" OD x 4.83" ID) 4.830 I 12,414.2 5,954.4 66.61 X0 BUSHING 5.5" x 5" crossover bushing (6.05" OD x 4.42" ID) Baker 5" 80-40 Seal bore extension (5.02" OD x4.0" 4.0" ID) 4.420 12,417.3 5,955.7 66.62 SBE 4.000 i, 12,435 8 5,962.8 66.59 X0 BUSHING 5" x 4 5" crossover bushYng (5.56" OD x 392" ID) 3 920 T TUbillg_Strifil_gS , . Tubing Description String 0... String ID .. Top (998) Set Depth (1... Set Depth (TVD) ... String Wt... String . I String Top Thrd TUBING 4. 5" @ 31 2' 3 1/2 2.992 31 2 12,434 4 5,962.3 9 30 L-80 EUE-m SURFACE, x 3.5" @ 2281' - 36-3,383 Completion Details I Top Depth I 1 (TVD) Top Ind Top (ftKB) (ftKB) (1 Item Description CornmeM ID (in) o 31.2 31.2 -0.03 HANGER FMC Tubing Hanger (11" x 4-1/2") 3.958 2,221.4 1,925.2 59.25 SAFETY VLV 4-1/2" Camco TRM-4PE/CF SSSV w/ 3.813" DB profile 3.812 2,281.2 1,955.0 61.51 X0 - Reducing 4.5" 12.6# L-80 IBTM crossoVer to 3.5" 9.3# L-80 EUE 3.500 I, f 1 12,311.0 5,914.2 67.25 NIPPLE Camco 3-1/2" DS Nipple (2.813" min ID) (Bore 2.812") 2.813 '' lik.. 12,415.6 5,955.0 66.62 LOCATOR LOCATOR 2.990 ilt 12,422 9 5,9579 66 631SEAL ASSY BakerGBH-22 80-40 Bonded Sea! assembly I I 1 3.000 GAS LIFT, 5,937 1 Perforations & Slots IIN Shot W.' Top (T1/11) Btu) (TVD) Top MKS) Ben (ftKB) 911(3) M Date KS) Zone Dens (Fh•-• _Type Comment 15,498.0 15,538.0 7,182.7 7,198.2 12/20/2009 6.0 IPERF 2.5" MILLENIUM, 60 degree phase GAS LIFT, t , ' ,.t . - 11,534 Notes: General & Safety End Date Annotation H 12/3/2009 NOTE: Well was originally named CD2-176; changed to CD2-76 when ddlling zone changed 12/3/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 111/ GAS LIFT, 12,262 Ir. a .: al. NIPPLE, 12,311 ..,te ' 11 )11 _ .., LOCATOR. 12,416 --- TUBING SPACER, ----- ____ I./ 12,417 SEAL ASSY, 12,423 11 1 1 MI Mandrel Details ' W -,..,..- Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run - Stn Top (ftKB) (KKK) 1") Make _ Model (in) Sep/ TYlhf TA. (in) (Phi) Run Date Com... 1 5,936 6 3,420.4 68.29 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 12/1/2009 IPE9F, 2 11,534.4 5,606.3 67.60 Camco KBMG 1 GAS LIFT GLV BK 0.125 1,634.012/25/2009 ,...... _ 15,498 15,538 - 3 12,262. 5,895.5 67.49 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 6/13/2010 LINER, i 1 12,383-15,767 TD (CO2-76), 15,769 i • • • Overview: CD2 -76: A re- perforation and stimTube stimulation will be performed in this Alpine C slant completion to return the well to production. A pressure build up indicates high skin damage possibly due to scale deposition. Procedure: 1. RU a -line and pressure test to 3500 psi ✓ 2. RIH with CCU20' 2.5" Millennium with 11 gm charges 60° phasing @ 6 SPF. Correlate to 12/20/09 HES Perforation Record and re- perforate 15,498'- 15,538' (2 runs required). 4. Rig down E -line. If production cannot be sustained, RU a -line and RIH with StimTube propellant .`✓ Set across from the perforated interval and detonate. POOH and RDMO. -, STATE OF ALASKA t ALAS IL AND GAS CONSERVATION COMMI ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell E Rug Fbrforations r Stimulate Other r Alter Casing r Rill Tubing r Perforate New Pool fl Waiver r - Time Extension E Change Approved Program fl Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Current Well Status: 5. Permit tQ Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r \ 209 - 098 3. Address: 6. I Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50- 103 - 20603 -00 7. Pro{serty Designation: 8. Well Name and NuVer: ADL 387212, 387211, 025530, 380095 F -AZ RL 7,0./0 CD2 9. Field /Pool(s): Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 15769 feet Plugs (measured) None true vertical 7298 feet Junk (measured) None Effective Depth measured 15769 feet Packer (measured) 12383 true vertical 7298 feet (true vertucal) 5942 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN 77 16 114 114 SURFACE 3346 10.75 3383 2387 INTERMEDIATE 12807 7.625 12841 6119 LINER 3384 4.5 15767 7297' Perforation depth: Measured depth: 15498' - 15538' ''t to a ?r l 1 I True Vertical Depth: 7165' - 7180' N!(' y 'F" k- :r1V iSSiOti Tubing (size, grade, MD, and TVD) 4.5 x 3.5, L - 80, 12434 MD, 5962 TVD Packers & SSSV (type, MD, and TVD) Baker 'HRD' ZXP liner top pkr @ 12383' MD and 5942' TVD SAFETY VLV - 4 -1/2" Camco TRM- 4PE /CF SSSV @ 2221 MD and 1925 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 15498'- 15538' MD Treatment descriptions including volumes used and final pressure: 130 bbls crude and 222 bbls seawater 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 695 1393 7 -- 270 Subsequent to operation 460 1372 41 -- 271 13. Attachments 14. Well Class after proposed work: \ Copies of Logs and Surveys run E xploratory r Development Service 15. Well Status after work: Oil Gas r" WDSPL r Daily Report of Well Operations XXX GSTOR r WAG r GASINJ r WIND r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Tim Schneider C, 265 -6859 Printed Name Tim h der Title WNS Staff Engineer Signature —/ " / '� /f Phone: 265 -6859 Date ' - -/G__ (0 • RBDMS SEP 13 20iFiti 3" 7/..7./ Form 10 -404 Revised 7/2009 Submit Original Only CD2 -76 Well Events Summary DATE SUMMARY • 1/27/10 TUBING OPEN 3.85" TO 2221' RKB LIGHT PARAFFIN ON TOOLS, CUT LI HT TO MODERATE PARAFFIN FROM 2400' SLM TO 4700' SLM TUBING OPEN 2.80 TO 15544' SLM. COMPLETE MOVE TO CD2 -463 2/19/10 TUBING OPEN 3.85" TO 2221' RKB LIGHT PARAFFIN ON TOOLS, TUBING OPEN 2.80 TO 5000' SLM. COMPLETE 3/1/10 RU LRS to perform a HPBD. PT to 3000 psi. LRS pumped 130 bbls dead crude at 2 bpm followed by 140 bbls SW pumped from the SW manifold at 1.5 bpm. Initial Tbg pressure was 400 psi dropping to 200 psi at 40 bbls, then gradually increasing to 1000 psi at 70 bbls and leveling out at 2200 psi from 100 -140 bbls crude; MTP was 2300 psi at 82 bbls of SW pumped (222 bbls total), dropping to 2000 psi at the completion of pumping SW. SITP = 0. 3/19/10 RAN MOTOR & 2.84" MILL SET DOWN IN NUMEROUS PLACES IN THE 3.5" TBG STARTING IN THE XO @ 2281' RKB. DID NOT SEE INCREASED MOTOR WORK- SUSPECT POSSIABLE PARAFFIN ON THE TBG WALLS. RIH TO 5200' CTMD. CHASED OUT W/ 130 DEG DIESEL WHILE TAKING RETURNS TO PRODUCTION. WELL ON LINE UPON DEPRATURE. JOB COMPLETE. 3/23/10 TAG FORMATION SAND @ 15524' SLM BAIL DOWN TO 15530' SLM RECOVER — 7 GAL OF FORMATION SAND, PULL 1" OV @ 12262' RKB, SET 1" OV (1/4" PORT) @ SAME. COMPLETE 4/15/10 PERFORM HOT TBG WASH FROM SURFACE TO 5000' CTMD. PUMP DIESEL W/ LRS PUMP & COIL PUMP AT 2.6 BPM @ 3000 PSI. GET 50 BBLS OF DIESEL PUSHED INTO THE PERFS WITH A FINAL PUMP PRESSURE OF 2940 PSI. JOB COMPLETE. 4/29/10 ENCOUNTERED "HYDRAFFINS" @ 1350' SLM. SCRATCHED HEAVY PARAFFIN f/ 600- 1900' & 2400 - 3000' SLM WITH 2.3 ". ATTEMPTED GAUGE TO 2.29 ", UNABLE TO PASS 1600' SLM. FLOW WELL OVERNIGHT. IN PROGRESS. 4/30/10 CUT HEAVY PARAFFIN f/ 600' - 1900' & 3000' - 3300' SLM. TBG OPEN TO 3.25" TO 2261' SLM & 2.80" TO 5000' SLM. IN PROGRESS. 5/1/10 CUT MODERATE PARAFFIN f/ 600' - 1900' SLM. TBG OPEN TO 3.85" TO 2221' RKB & 2.80" TO 5000' SLM. COMPLETE. CREW RETURNED TO KUPARUK. 5/12/10 ENCOUNTERED MINIMAL PARAFFIN. TUBING OPEN 2.80" TO 3500' SLM, 3.60" TO 2283' RKB, 3.85" TO 2221' RKB. COMPLETE. 5/21/10 ENCOUNTERED LIGHT PARAFFIN. TBG OPEN TO 2.80" TO 12311' RKB. IN PROGRESS. 5/22/10 TAGGED @ 15544' SLM. TOOLS HUNG UP BELOW SSSV; POSSIBLY PARAFFIN PREVENTING FULL OPENING FLAPPER. PUMPED HOT DSL, WORKED TOOLS FREE. CUT PARAFFIN WITH 2.6" SCRATCHER TO 3500' SLM. IN PROGRESS. 6/3/10 ENCOUNTERED LIGHT PARAFFIN FROM 400' TO 1800' SLM. TUBING OPEN 2.05" TO 3000' SLM. JOB POSTPONED DUE TO HIGH WINDS. IN PROGRESS. 6/4/10 CONFIRMED ICE PLUG @ 2024' SLM. IN PROGRESS. i r t p ° a S WNS a CD2 -76 CoInoc+C?I fillips I. Well Attributes Max Angle & MD TD A , 1 )Y r , e Weilbore APUUWI Field Name Well Status Inc! (`) MD Kt K6 (H ) Act Bim KB) {` 501032060300 ( ALPINE P1100 69 94 I 12,734.20 _ 15,769.0 Comment 1125 (ppm) 'Date lAnnotation I End Date KB - Grd (ft) Rig Release Date g SSSV TRDP Last WO. 43 87 12/2/2009 wen coot. HORIZg(tTAt,, S 2,7,4 41.49-416-k 40,4�t . _, : --- Sr GC - I I Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag SLM 15,544 0 5/22/2010 Rev Reason: GLV C /O, Pull Catcher, Set CS shut -in tool Imosbor 6/14/2010 INNGER,31 __.. .._ ,. -..... Casinr Strin•S .. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 14.688 37.0 114.0 1146 109.00 H -00 Welded lliteill Insulated 24" Casing Description String 0... String ID . Top (ftKB) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd / C Casing Description String 0... String ID Top (11KB) Set Depth (f Set Depth (TVD) ... String Wt... String L ill TE EDTE 7 58 6.875 34 1 12 840 7 6 115 ring ... String Top Thni INTERMEDIATE 5 29.70 L -80 BTCM S URFACE 10 3/4 9 950 36 338 6 2 386 5 45.50 L -80 BTC -m --- LINER 412 3.958 12,383.0 15,767.1 7,297.4 12.60 L -80 SLHT 1111 CONDUCTOR Insulated 24'. Liner Details 7 31'.4 Top Depth (TM Top Inel Nomi... " ^ Top (ftKB) () ( °) Item Description Comment ID (in) 12,383.0 5,942.0 66.54 PACKER Baker"HRD" ZXP Liner top packer 5 - 1/2" x 7 - 5/8" (6.55" OD x 4.95" ID) 4.950 SAFETY VLV. " IM 12,402.0 5,949.6 66.59 NIPPLE - "RS" Packo6 Seal Nipple -5 -1/2 (6.06' OD x4.875" ID) 4.875 2.221 12,404.8 5,950.7 66.59 HANGER Baker Flex- lock liner hanger- 5 -1/2" x 7-5/8"(6 6" OD x 4.83" ID) 4.830 et 12,414.2 5,954.4 66.61 X0 BUSHING 5.5" x 5" crossover bushing (605" OD x 4.42" ID) 4.420 12,417.3 5,955.7 66.62 SBE Baker 5" 80 -40 Seal bore extension (5.02" OD x 4.0" ID) 4.000 12,435 -8 5,962.8 66 59 X0 BUSHING 5" x 4 -S" crossover bushing (5 56" OD x 3 92" ID) 3.920 i! Tubing Strings Tubing Des ription String O String ID Top (ftKB) Set Depth (f Set Depth (ND) .. 'String Wt... String String Top Thrd TUBING 4.5x3 5 I 3 1/2 962 3 m i 9 30 L 80 I EUE SURFACE. � (: Completion Details 36 -3,383 Top Depth (ND) Top Intl Nomi... Top (ftKB) (MKB) (•) Item Description Comment ID (in) 31.2 31.2 -0.03 HANGER FMC Tubing Hanger (11" x 4 -1/2 ") 3.958 2,221.4 1,925.2 59.25 SAFETY VLV 4-1/2" Camco TRM-4PE /CF SSSV w/ 3.813" DB profile 3.812 2,281.2 1,955.0 61.51 X0 - Reducing 4.5" 12 6# L-80 IBTM crossover to 3.5" 9.3# L-80 EUE 3.500 1 ' ! 12,311.0 5,914.2 67.25 NIPPLE Carrico 3 -1/2" DS Nipple (2.813" min ID) (Bore 2.812 ") 2.813 I 12,415.6 5,955.0 66.62 LOCATOR LOCATOR 2.990 '. 12,422.9 5,957.9 66.63 SEAL ASSY BakerGBH -22 80 -40 Bonded Seal assembly 3.000 liti GAS LIFT, �..: Perforations &Slots 5,937 Shot Top (TVD) Btm (TVD) Dens lir Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date ' (sh Type ' Comment 15,498 15,538 7,182.7 7,198.2 11220/2009 6.0 IPERF 25" MILLENIUM, 60 degree phase GAS 1 urn, * . Note End Da te NOT VV originally named CD2 -176; Entl Date Annotation s i 12/3/2009 changed to CD2 -76 when drilling zone changed 12/3/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9. 0 Mr GAS LIFT, _ 12,262 III NIPPLE, 12,311 --- -- - - -- -- _ 11 I l LOCATOR, 12,416 PANG SPACCER, -- . .. a 12,417 SEAL ASSY, 12,423 all - ry tolls - - - -_ Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run NTERMEDIATE, Stn To➢ (60(9) (ftKB) 11 Make Model (in) Sere Type TYPe (in) (Pei) Run Date Can... - t2,841 1 5,936.6 3,420.4 68.29 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 12/12009 15.498- 15.536 IPERF, _. -_ 2 11,534. 5,606.3 67.60 Camco KBMG 1 GAS LIFT GLV BK 0.125 1,634.0 12/25 12,2 2009 -« _. _ - . . _ ...... _ - - ` " 3 12,262.0 5,895.5 67.44 9 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 6/13/2010 II INER, J 72,383 - 1 TO (052.76), 15,769 I J .G-1.4gQ1 .{ 2 7 2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION i3K 1t & Gas Cons. Commis I WELL COMPLETION OR RECOMPLETION REPORT AND4 la. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb. Well Class: 20AAC 25.105 20AAC 25.110 Development 111 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: December 2, 2009 209 - 098 / 309 - 383 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 October 19, 2009 50 103 - 20603 - 00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Om Surface: 2218' FNL, 2064' FEL, Sec. 2, T11 N, R4E, UM November 27, 2009 CD2 - 76 1 Top of Productive Horizon: 8. KB (ft above MSL): 52' RKB 15. Field /Pool(s): 2628' FSL, 353' FWL, Sec. 27, T12N, R4E, UM GL (ft above MSL): 15.6' AMSL Colville River wield Total Depth: 9. Plug Back Depth (MD + TVD): 1 2446' FNL, 181' FWL, Sec. 27, T12N, R4E, UM 15769' MD / 7298' TVD "Alpirte- OtTeet 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 371170 y - 5974149 Zone 4 15769' MD / 7298' TVD ADL 387212, 387211, 025530, 380095 TPI: x - 363193 y - 5984417 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit Total Depth: x 363024 y - 5984626 Zone 4 2221' MD / 1924' TVD 380075 ‘ , 18. Directional Survey: Yes El No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) approx. 1500' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD GR/Res not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# 1-1-40 37' 114' 37' 114' 24" 5.5 sx Portland III 10.75" 45.5# L -80 37' 3382' 37' 2387' 13.5" 1 526 sx ASLite, 276 sx Class G 7.625" 29.7# L -80 37' 12841' 37' 6119' 9.875" 295 sx Class G, 44 bbls Class G 4.5" 12.6# L -80 12383' 15767' 5942' 7297' 6.75" slotted-liner 6,05 - 5 X / is S8 C 31 /o 24. Open to production or injection? Yes is No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5" x 3.5" 12434' 12383' MD / 5942' TVD 15498'- 15538' MD 7165-7180' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 26, 2009 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 12/27/2009 9 hours Test Period - -> 487 733 80 100% 1791 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 263 psi 1102 24 -Hour Rate -> 1227 2198 214 not available 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. C07 .L F % w '. or NONE � � t3 Form 10 -407 Revised 12/2009 RE3DMS JAN 2 7 Q ED ON REVERSE Subm original only „4.-fil' �W"+M�rt _MINI qR w_ i 28. GEOLOGIC MARKERS (List all formations and markers�untered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1583' 1500' needed, and submit detailed test information per 20 AAC 25.071. C -30 3462' 2415' C -20 4357' 2828' K -3 7052' 3841' K -2 7605' 4058' Nanuq 12230' 5883' K -1 15209' 7066' Kuparuk 15426' 7152' Alpine 15472' 7171' N/A CD2 -76PB1 TD 16548' 7519' CD2 -76PB2 TD 13349' 6312' Formation at total depth: Alpine C 30. LIST OF ATTACHMENTS Summary of Daily Operations, Final directional survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nina Anderson @ 265 - 6403 \r j Printed Name G. Alvord Title: Alaska Drilling Manager Signature . Phone 265 - 6120 Date f �� Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 • CD2 -76 Well Events Summary DATE SUMMARY 12/10/09 PERFORMED MUD CLEAN OUT TO HARD TAG @ 15677 CTMD USING SLICK S/W, FREEZE PROTECTED I/A & TUBING TO 3500 FT WITH DIESEL, READY FOR E -LINE. 12/17/09 PERFORMED STEM TEST ON BOP ON WELLHEAD. STEM TESTED BOP TO 5000 PSI. 12/18/09 UNABLE TO PERFORATE WELL DUE TO ELECTRICAL PROBLEMS IN UNIT. IN PROGRESS... 12/19/09 ON STANDBY WHILE LOGGING UNIT IS GETTING NEW ALTERNATOR, 80 AMP FUSE AND BATTERIES. 12/20/09 COMPLETED PERFORATING CD2 -76. PERFORATED 15498' - 15538' WITH 2.5" GUN, 11g MILLENIUM DEEP PENETRATING CHARGES, 6SPF 60 DEGREE PHASING. T /I /0 AFTER FIRST PERFORATIONS = 1150/1200/250. T /I /0: AFTER SECOND PERFORATIONS = 1300/1300/325. GOT STUCK AT 350' COMING OUT OF THE HOLE WITH SECOND RUN. CLOSED BOPS, SHUT SSSV, BLEED TUBING TO 0 PSI AND STRIPPED LINE OUT OF GREASE TUBES. WIRE APPEARS WOBBLED AROUND STUCK SECTION. REPLACE GREASE HEAD WITH PACKOFF, STAB ON WELL, OPEN BOPS, 0 PSI WELLHEAD PRESSURE. ATTEMPT TO POOH, UNABLE TO MOVE UP OR DOWN, DECISION MADE TO PULL OUT OF WEAKPOINT, 0 PSI WELLHEAD PRESSURE, RDMO. FINAL TUBING PRESSURE 20 PSI. 12/22/09 RETRIEVED PERF GUNS AND TOOLSTRING FROM 15,529' SLM. IN PROGRESS. 12/23/09 ATTEMPTED TO SET CATCHER SUB ON DS NIPPLE @ 12,311' RKB, CATCHER FELL THROUGH INTO 4 1/2" LINER. RECOVERED CATCHER FROM 15,558' SLM. IN PROGRESS. 12/24/09 MEASURED BHP @ 12,281' RKB (MAX PSI 3677.69 / TEMP 130.62) SET 3 1/2 SLIP STOP CATCHER © 12290' SLM. PULLED 1" SOV @ 12262' RKB. IN PROGRESS 12/25/09 PULLED 1" DV @ 11534' RKB, SET 1" GLV @ SAME (1/8" PORT, TRO =1634) SET 1" OV @ 12262' RKB (1/4" PORT) LDFN IN PROGRESS 12/26/09 PULLED SLIP STOP CATCHER @ 12290' SLM. COMPLETE WNS • CD2 -76 ConocoPhilli !"" $ WejA,�tributes Max Angle & MD TD Al I j . � f m4: Welibora APUUWI Field Name Well Status ' Inc' ( °) MD (ftKB) Act BM (7(6) c.axnccafRxlNtp 501032060300 ALPINE DRILLING 69.94 12,/3420 15 /690 Comment (125 (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date I • - • Wett Coe8g H0Rl0QNTA„„,pM12i320C5 33, 'M SSSV. TRDP Last WO. 4387 _ 12/2/2009 7 gCbcrstic 7 Annotation 'Depth(ftKB) End Date Annotation Last Tag Rev Reason: NEW WELL _ 'Last Mod ... 1 Entl Date 12/3/2009 nANCeR. 3, ° Casin • Strin • s Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 37.0 114 -0 114 0 62.50 11-40 Welded Insulated 24" Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd t SURFACE 10 3/4 9.950 36.5 3382.6 2,386.5 45.50 L BTC - m Casing Description Str ng 0... String ID ... Top (f6CB) Set Depth (f.. Set Depth (ND) ._ String Wl... String ... String Top Thrd INTERMEDIATE 7 5/8 6.875 341 12,840.7 6.116 3 29.70 L BTCM Casing Description Str ng 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thed I 41/2 3.958 12,383.0 15,767.1 7,297.4 1260 L , SLHT Insulated 24 CONDUCT N Liner Details -.. ..___ 37 -116 Top Depth (ND) Top Incl Nonni... Top(ttKB) (BKB) ("1 Item Description __ -- Comment ID(in) 12,383.0 5,942.0 66.54 PACKER Baker "HRD" ZXP Liner top packer-5-1/2" x 7-5/8" (6.55" OD x4.95" ID) 4.950 12,402.0 5,949.6 6659 NIPPLE "RS" Packoff Seal Nipple -5 -1/2 (6.06" OD 4.875" ID) 4.875 SAFETY VLV. _ _.....,. .. �. 2221 12,404.8 5,950.7 66.59 HANGER Baker Flex- lock li ner hanger- 5 -1/2" x 7-5/816.6" 0 x4.83" ID) 4.830 12,414.2 5,954.5 66.61 X0 BUSHING 5.5" x 5" crossover bushing (6.05" OD x 4.42" ID) 4.420 12,417.3 5,955.7 66.62 SBE Baker 5" 80-40 Seal bore extension (5 02' OD x 4.0" ID) 4.000 12,435.8 5,962.8 66.59 X0 BUSHING 5" x 4.5" crossover bushing (5.56" OD x 3 92" ID) 3.920 Tubing Strings ._ Tubing g Description String 0... String ID Top (ftKB) Set Depth (1.. Sot Depth (TVD) ... String W . Str g .. String Top Thnl ' Completion 3 12 2 992 1 31 2 12,434.4 5 9.30 _ L-80 .. I EUE m TUBING tion Details .__. SURFACE. �. , Top Depth: 36-3.383 1 (TV0) Top Inc] Wank.. �: Top(nKBI MB) C) Item Description Comment ID(in) 31.2 31.2 0.27 HANGER FMC Tubing Hanger (11" x 4 -1 /2") 3.958 2,221.4 1,924.0 58.96 SAFETY VLV 4 -1/2" Camco TRM- 4PE /CF SSSV w/ 3.813' DB profile 3.812 i'. 2,281.2 1,955.0 61.49x0 Reducing Crossover 4.5 x 3.5" 3.500 _-... NIPPLE Camco 3 -1/2" DS Nipple (2.813" min ID) (Bore 2.812") 2.813 .4 1 . ff 12,415.6 5,955.0 66.62. /2,422 -9 5,957.9 66.63 LOCATOR LOCATOR 2.990 i SEAL ASSY BakerGBH -22 80 -40 Bonded Seal assembly 3.000 illt Notes: General & Safety . End Date 1 Annotat'w 2/ ._. - 5,937 12/3/2009 I NO TE Well was originally named CD2- 176; _ changed to CD2 -76 when dolling zone changed 12/3/2009 NOTE VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, It 11,534 Mt GAS LIFT, 12,262 P lit NIPPLE, 12,311, [ 1- 1 1 LOCATOR, 12,416 TUBING SPACER,- 85 + g 12,417 SEAL ASSY. _.__ • 12,423 -- lf KOP 92, 12,604 0110 Mandrel Details �, Top Depth Top Port •r (ND) Inc! OD Valve Latch Sae TRO Run Stn To • KB (ftKB) ( °) Make Model (n) Saw Type TYP■ 0) (psi) Run Data Com... 5,936.6 3,420.5 68.54 Camco 1KBMG 1 GAS LIFT DMY BK 5 0.6w 0.0 12/1/2009 NTERMEDIATE, } - - -- - � -- 3412841 --- . `" j 11,534.4 5,605.8 6700 Camco IKBMG 1 GAS LIF DMY BKS 0000 0.012/112008 IN 12,262.0 5,895.4 67.55 Cameo KBMG 1 GAS LIFT SOV BEK 5 0.000 0.0 12/1/2009 DCK -2 n LINER, -� 1 12,38315,767 TD (CD2 -76), 15,769 • ion ©c ©Phillips Time Log & Summary WelIview Web Reporting Report Well Name: CD2 - 76 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 10/18/2009 5:00:00 PM Rig Release: 12/2/2009 9:00:00 AM Time. Logs Date ?, From : To Dur";. " S. Depth E. Depth Phase Code Subcode T " Comment 10/18/2009 24 hr summary Move Rig f/ CD2 -60A to CD2 -173 (Non- Inline Move) - Spot Sub, Pits & Motors and Ball Mill - Connect Service Lines and Hi -Line Power - N/U Riser and Associated Lines - P/U 5" 30 Stands of 5" DP and 8 Stands of 5" HWDP Rig Accepted © 1700 Hours 08:00 15:00 7.00 0 0 MIRU MOVE PSIT P Move out Pit & Motor complexes - skid rig on subbase - back sub off of well - Move rig to CD2 -176 - center rig over well - Skid rig to drill position - Move in pipe shed - spot up Pit & Motor Complexes - 15:00 17:00 2.00 0 0 MIRU MOVE PSIT P Connect Steam, air and water service lines - Highline power on @ 1700 hrs. Accepted rig @ 1700 hours. 17:00 19:00 2.00 0 0 MIRU MOVE NUND P N/U Suraface Riser - Hook Up Mud, Flow & Drain Lines - Take On Spud Mud 19:00 00:00 5.00 0 0 MIRU MOVE PULD P PJSM; P/U 90 Jts of 5" DP and 24 Jts of HWDP f/ Pipe Shed 10/19/2009 R/U E -Line Gyro - M/U BHA #1 and Orient UBHO /MED - Hold Pre -Spud Meeting w/ Crew - Fill Riser and Pressure Test Surface Lines t/ 3500 Psi - Drill 13 1/2" Hole w/ Motor f/ 114' - 1,188' MD, Taking Gyro Check Shots Every Stand 00:00 00:45 0.75 0 0 MIRU MOVE PULD P PJSM - Pick up and stand back (2) 8" flex drill collars and drilling jars 00:45 02:30 1.75 0 0 MIRU RIGMNT SLPC P Slip and cut drilling line - Service Top Drive & Drawworks 02:30 03:00 0.50 0 0 MIRU DRILL RURD P PJSM - RU Halliburton E -line gyro - hang top sheave on monkey board 03:00 06:00 3.00 0 0 SURFA( DRILL PULD P MU BHA #1: Bit, ABI motor, IBS, EM collar, EM index sub, Antenna sub, FS, UBHO sub - orientate UBHO / MED 06:00 06:30 0.50 0 0 SURFA( DRILL SFTY P Held Pre -Spud Meeting with rig crew and support personnel 06:30 07:00 0.50 0 0 SURFA( DRILL PRTS P M/U NMFDC's and Jars - Fill Riser and Pressure Test Surface Lines t/ 3500 Psi 07:00 12:00 5.00 0 354 SURFAt DRILL DDRL P Drilled 13 1/2" Hole w/ Motor f/ 114' - 354' MD - Backing Up MWD w/ Gyro Surveys Each Stand ADT -2.45, AST -0.42, ART -2.03 P/U 100, S/O 98, Rot 97 Torque 6,000/4,500 @ 40 RPM 450 GPM @ 600 Psi Page 1 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 354 1,188 SURFAt DRILL DDRL P Drilled 13 1/2" Hole w/ Motor f/ 354' - 1188' MD - Taking Gyro Check Shots Each Stand to Back Up MWD Data ADT- 5.62, ART- 2.97, AST- 2.65 P/U 145, S/O 120, Rot 120 Torque 6,500/4,000 @ 40 RPM 450 GPM @ 920 Psi 10/20/2009 Continue to drill 13 1/2" Hole w/ Motor from 1,188' MD to 2883', trouble shoot pump #2, change liner and swab, continue to directional drill from 2883' to 3093' TVD 2275'). 00:00 12:00 12.00 1,188 2,331 SURFAt DRILL DDRL P Continue to directional drill 13 1/2" hole w/ motor (1.83 deg bend) from 1,188' - 2,331' MD 1,980 TVD Actual drilling time 6.65 hours. Actual rotating 4.49 hrs, sliding 2.16 hrs. Hours on jars # 17710057 = 101.5. Drilled w/ 15 -35k weight on bit, rotating 40 to 45 rpm, torque on bottom 7 to 8k ft Ibs, torque off bottom 6k ft lbs. Pumping 450 to 800 gpm w/ 920 to 2250 psi. PU wt 130k, SO wt 120k to 110k, Rot wt 129k. 12:00 17:00 5.00 2,331 2,883 SURFA( DRILL DDRL P Continue to directional drill 13 1/2" hole w/ motor (1.83 deg bend) from 2331' MD to 2883'. Actual drilling time 4.2 hours. Actual rotating 3.64 hrs, sliding .56 hrs. Hours on jars # 17710057 = 105.7 Drilled w/ 15 -35k weight on bit, rotating 50 rpm, torque on bottom 8k ft Ibs, torque off bottom 6k ft Ibs. Pumping 800 gpm w/ 2240 to 2420 psi. PU wt 130k, SO wt 120k to 117k, Rot wt 129 to 125k. 17:00 18:45 1.75 2,883 2,883 SURFAt DRILL CIRC T Lost pump pressure, trouble shoot # 2 mud pump. Gravel under valve, change liner and swab. Continue to circulate and work pipe. Pumping 378 gpm w/ 770 psi. 18:45 00:00 5.25 2,883 3,093 SURFAt DRILL DDRL P Continue to directional drill 13 1/2" hole w/ motor (1.83 deg bend) from 2883' to 3093' (2275' TVD). Actual drilling time 3.76 hours. Actual rotating 3.68 hrs, sliding .08 hrs. Hours on jars # 17710057 = 109.46. Drilled w/ 15 -35k weight on bit, rotating 60 rpm, torque on bottom 8 to 9k ft Ibs, torque off bottom 6 to 6.5k ft lbs. Pumping 800 gpm w/ 2470 to 2600 psi. PU wt 130k, SO wt 117 to 110k, Rot wt 125k. Page2 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/21/2009 24 hr Summa Continue to drill 13 1/2" hole w/ motor from 3093' to 3209' (2320' TVD), work on #2 mud pump liner wash pump, replace liner and swab # 2 mud pump, continue to drill 13 1/2" hole w/ motor from 3209' to 3326' (2365' TVD), replace another liner and swab in #2 mud pump, continue to drill 13 1/2" hole w/ motor from 3326' to 3393' (TD)(2391' TVD), circulate and condition mud and hole, backream to HWDP at 908', observe well- OK- slight losses, run in the hole to TD at 3393',, circulate and condition mud and hole, pull out of the hole to the HWDP (908'), monitor well -OK- slight losses, pull HWDP to the jars at 170', lay down the jars and two NMDC's, lay down the rest of BHA #1, clean and clear rig floor, rig up to run 10 -3/4" casing, pre job safety meeting on running 10 -3/4" casing. 00:00 01:00 1.00 3,093 3,209 SURFA( DRILL DDRL P Continue to directional drill 13 1/2" hole w/ motor (1.83 deg bend) from 3093' to 3209' (2320' TVD). Actual drilling time 1.06 hours. Actual rotating 1.06 hrs, sliding 0 hrs. Hours on jars # 17710057 = 110.52. Drilled w/ 15 -35k weight on bit, rotating 60 rpm, torque on bottom 8 to 9k ft Ibs, torque off bottom 6 to 6.5k ft Ibs. Pumping 800 gpm w/ 2470 to 2600 psi. PU wt 132k, SO wt 118 to 110k, Rot wt 126k. 01:00 02:00 1.00 3,209 3,209 SURFA( RIGMNT RGRP T Liner wash Motor /pump coupling #2 pump failed - replace coupling - Reciropate and circ 300 gpm / 625 psi 02:00 03:30 1.50 3,209 3,209 SURFA( DRILL CIRC T Replace Liner and swab #2 pump, right cylinder Reciropate and circ 300 gpm / 625 psi 03:30 05:15 1.75 3,209 3,326 SURFA( DRILL DDRL P Continue to directional drill 13 1/2" hole w/ motor (1.83 deg bend) from 3209' to 3326' (2365' TVD). Actual drilling time 1.20 hours. Actual rotating 1.13 hrs, sliding .07 hrs. Hours on jars # 17710057 = 111.72. Drilled w/ 15 -30k weight on bit, rotating 60 rpm, torque on bottom 8k ft Ibs, torque off bottom 6.5k ft Ibs. Pumping 750 gpm w/ 2380 to 2440 psi. PU wt 133k, SO wt 112 , Rot wt 125k. 05:15 06:00 0.75 3,326 3,326 SURFA( DRILL CIRC T Replace Liner and swab #2 pump, left cylinder Reciropate and circ 300 gpm / 625 psi Page 3 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode - T Comment 06:00 07:15 1.25 3,326 3,393 SURFA( DRILL DDRL P Continue to directional drill 13 1/2" hole w/ motor (1.83 deg bend) from 3326' to 3393' (2391' TVD). Actual drilling time 0.61 hours. Actual rotating 0.61 hrs, 0 sliding hrs. Hours on jars # 17710057 = 112.33. Drilled w/ 10 -20k weight on bit, rotating 60 rpm, torque on bottom 8k ft lbs, torque off bottom 6.5k ft lbs. Pumping 800 gpm w/ 2500 to 2760 psi. PU wt 138k, SO wt 115 , Rot wt 125k. 07:15 09:15 2.00 3,393 3,393 SURFA( DRILL CIRC P Circulate and condition mud - 800 gpm / 2600 psi / 50 rpm @ 7.5 to 9k K torque 09:15 12:00 2.75 3,393 1,665 SURFA( DRILL REAM P Backream out of the hole from 3393' to 1665'. Pumping 750 gpm w/ 2200 psi, rotate 60 rpm w/ 7.5k ft Ibs of torque. 12:00 12:15 0.25 1,665 1,500 SURFA( DRILL REAM P Continue to backream out of the hole from 1665' to 1500' (base of permafrost). Pumping 750 gpm w/ 2200 psi, rotate 60 rpm w/ 7.5k ft Ibs of torque. 12:15 12:45 0.50 1,500 908 SURFA( DRILL REAM P Continue to backream out of the hole from 1500' to 908' (HWDP). Pumping 500 gpm w/ 1100 psi, rotate 60 rpm w/ 5k ft Ibs of torque. 12:45 13:00 0.25 908 908 SURFA( DRILL OWFF P Flow check -OK, slight losses. 13:00 14:30 1.50 908 3,393 SURFA( DRILL WPRT P Run in the hole on elevators f/ 908' to 3393'. Hole in good shape. 14:30 15:45 1.25 3,393 3,393 SURFA( DRILL CIRC P Circulate and condition mud at 3393'. Pumping 800 gpm w/ 2600 psi. 15:45 18:15 2.50 3,393 908 SURFA( DRILL TRIP P Pull out of the hole to the heavy weight drill pipe, monitor well on the trip tank. 18:15 18:30 0.25 908 908 SURFA( DRILL OWFF P Monitor well at the HWDP- OK, slight losses. 18:30 19:15 0.75 908 170 SURFA( DRILL TRIP P Pull HWDP, monitor well on the trip tank. 19:15 21:30 2.25 170 0 SURFA( DRILL PULD P Lay down the jars, and two 8" NM DC's, UBHO, float sub, antenna sub, index sub, EM collar, integral blade stabilizer, 8" motor and Hughes 13 -1/2" bit. Calculated displacement for the trip = 40 bbls, actual 49.5 bbls. 21:30 22:00 0.50 0 0 SURFA( DRILL PULD P Clean and clear rig floor. 22:00 23:30 1.50 0 0 SURFA( CASING RURD P Rig up to run 10 -3/4" casing 23:30 00:00 0.50 0 0 SURFA( CASING SFTY P Pre job safety meeting prior to running 10 -3/4" casing. Page 4of58 • • Time Logs Date From To Dur S. Depth E. Depth Phase ! Code l Subcode T Comment 10/22/2009 24 hr Summary Run 10 -3/4" 45.5 ppf L -80 BTC -m casing, tagged an obstruction @ 909'. Engage Frank's fillup tool and circulate jt # 23 and #24 down to 980'. Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing to 1835 (jt # 45), circulate 140 bbls (bottom's up +), continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing to 3340' (jt #82). Make up FMC hanger and landing joint, land casing @ 3382', rig down Frank's fillup tool, rig up Dowell cementing head, circulate and condition mud and hole for cement. Lower YP f/ 70 to 19. Hold PJSM. Cement casing w/ Dowell Schlumberger, full returns, 139 bbls 10.7 ppg ASL lead cement to surface, bumped plug to 1050 psi, floats held, CIP @ 1457 hrs.- see time breakdown 12:15hrs to 1500 hrs. Rig down cement equipment, nipple down riser, nipple up FMC Alpine II wellhead, verify alignment, test metal to metal seal to 1000 psi f/ 10 minutes. Nipple up BOPE equipment. Pre job safety meeting on picking up 5" drill pipe and standing back in the derrick. Pick up 72 jts of 5" drill pipe /stand back in the derrick, lubricate rig, continue to pickup 9 more joints of drill pipe. 00:00 01:00 1.00 0 106 SURFA( CASING RNCS P Run 10 -3/4" 45.5 ppf L -80 BTC -m casing: Install bow spring on stop 8' above the shoe and on the box of jt # 1, baker lock joint #2, install centralizer on stop 10' below box, bakerlock/ makeup float collar joint w/ centralizer on box of joint #3, bakerlock pin of joint #4. Stab Frank's fillup tool into box of jt #4, then circulate 40 bbls of mud to clear air and check float equipment while still in the conductor. 01:00 02:45 1.75 106 909 SURFA( CASING RNCS P Continue to run casing observing makeup mark. Torque casing to 8600 ft lbs of torque. Obtain PU and SO wt's per Rig engineer every 10 joints. Apply Bow spring centralizers on every box to jt #12, then every other box to jt # 80. Ran casing to jt # 23 plus 10' of jt # 24 in the hole, tagged an obstruction (Taking 20k weight) @ 909'. 02:45 03:30 0.75 909 980 SURFA( CASING CIRC P Engage Frank's fillup tool and circulate jt # 23 and #24 down. Pumping 5 bpm w/ 250 psi and 29% flow. PU wt 120k, SO wt 105k. Circulated 180 bbls (3 BU). 03:30 05:00 1.50 980 1,835 SURFA( CASING RNCS P Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing. Torque casing to 8600 ft lbs of torque. Obtain PU and SO wt's per Rig engineer every 10 joints. Run from jt # 25 to jt # 45. 05:00 05:30 0.50 1,835 1,840 SURFA( CASING CIRC P Engage Frank's fillup tool and circulate jt # 45. Stage pumps up from 2 bpm w/ 270 psi and 17% flow out to 6 bpm w/ 380 psi and 31% flow out. PU wt 141k, SO wt 120k. Circulated 140 bbls ( BU plus). After circulating PU 140k, SO 130k. 05:30 07:45 2.25 1,840 3,340 SURFA( CASING RNCS P Continue to run 10 -3/4" 45.5 ppf L -80 BTC -m casing. Torque casing to 8600 ft Ibs of torque. Obtain PU and SO wt's per Rig engineer. Run from jt # 46 to jt # 82. Page 5 of 58 • • Time Logs Date " From To Dur S. Depth ' E. Depth Phase Code Subcode T Comment 07:45 08:00 0.25 3,340 3,383 SURFA( CASING RNCS P Make up FMC hanger w/ landing joint. Run in the hole and land on the hanger. PU wt 202, SO wt 135k. 08:00 09:30 1.50 3,383 3,383 SURFA( CEMEN" RURD P Rig down Franks' fillup tool. Rig up Dowell /Schlumberger cementing head. Bottom seal on cement head would not stay in seal groove - required several attemps to install head. 09:30 12:15 2.75 3,383 3,382 SURFA( CEMEN" CIRC P Circ and cond. mud for cementing, staged pump rate up from 2.5 bpm / 260 psi to 7 bpm / 350 psi, cond. mud to 10.0 ppg. in and out - lower YP from 70 to 19. St wt up 185K, do wt 148K. Held Prejob safety and opts meeting with rig team. 12:15 15:00 2.75 3,382 3,382 SURFA( CEMEN "CMNT P Cemented 10 3/4" casing as follows: Rig pumped 99 bbls of 10.0 ppg mud with nut plug marker followed with 33 bbls of Biozan as pre flush w/ nut �,/ plug marker. Line up to Dowell and /� pumped 3 bbls of FW, tested lines to 2500 psi . Dropped bottom plug. Mixed & pumped 50 bbls of 10.5 ppg MudPUSH II spacer, ave. 5.2 bpm at 180 psi. Mixed & pumped 428 bbls (526 sxs) 10.7 ppg lead slurry at 4.57 yield (ASL) ave. 7.2 bpm at 266 to 136 psi. Observed nut plug marker at shakers w/ 410 bbls lead slurry pumped (pumped down surge can, 428 bbls total) Switched to tail slurry and pumped 57.6 bbls (276 sxs) of 15.8 ppq tail cmt at 1.17 yield (Class G w/ additives) ave. 5.5 bpm at 160 psi. Dropped top plug w/ 20 bbls fresh water f/ Dowell, Switched to rig pumps & displaced cement w/ 297 bbls 10.0 ppg mud ave. 7.8 bpm, ICP 230, FCP 700 psi, slowed pump to 4 bpm at 520 psi (for the last 7 bbls of displacement) Bumped plug to 1,050 psi. Checked floats OK, CIP @ 1457 hours. Had full circulation throughout job w/ 139 bbls of 10.7 ppg cement returns to surface. Reciprocated pipe until last 158 bbls of displacement, lost 25K SOW and landed hanger. 15:00 16:30 1.50 3,382 0 SURFA( CEMEN" CMNT P Blow down cement line - Rig down cement head and line - Rd casing elevators - LD landing joint - Change out casing bails with Drill pipe bails 16:30 18:00 1.50 0 0 SURFA( DRILL NUND P Nipple down riser, remove FMC slip lock casing head Page 6 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase " Code Subcode T ' Comment 18:00 19:15 1.25 0 0 SURFA( DRILL NUND P Nipple up FMC Alpine Gen II wellhead. Alignment verified by Rig Supervisor Granville Rizek and FMC rep Rob Wells. Test metal to metal seal to 1000 psi for 10 min. Witness of test by Rig supervisor Granville Rizek and FMC rep Rob Wells. 19:15 20:30 1.25 0 0 SURFA( DRILL NUND P Nipple up BOPE stack. Tighten clamp on 1" 5M wellhead. Attatch drain lines. 20:30 20:45 0.25 0 SURFA( DRILL SFTY P Pre job safety meeting prior to rigging up to pick up " drill pipe. 20:45 21:00 0.25 0 0 SURFA( DRILL RURD P Rig up to pick up 5" drill pipe from the pipe shed and stand back in the derrick via the mouse hole. 21:00 21:15 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting on picking up 5" drill pipe. 21:15 23:00 1.75 0 0 SURFA( DRILL PULD P Pickup and rabbit 5" "S" and "G" drill pipe to 2.85 ". Stand back in the derrick. A total of 72 jts picked up. 23:00 23:30 0.50 0 0 SURFA( DRILL SVRG P Service rig. 23:30 00:00 0.50 0 0 SURFA( DRILL PULD P Continue to pickup and rabbit 5" "S" and "G" drill pipe to 2.85 ". Stand back in the derrick. A total of 9 jts picked up. 10/23/2009 Continue to pick up 5" drill pipe /stand back in the derrick, Finish nippling up BOPE: Install bell nipple, hook up flow line. Pickup Sperry Sun Geo -Span to the rig floor, Slip and cut 60' of 1 -3/8" drilling line. Service top drive, adjust brakes on the drawworks. RU to test BOPE. Test BOPE: Witness of test by AOGCC inspector John Crisp. Test w/ 5" test joint: Annular to 250 psi low and 2500 psi high. Test upper pipe (3 -1/2" x 6" variable), lower pipe (3 -1/2" x 6" variable) and blinds, inside and outside kill and choke valves, all valves in the choke manifold and 4" valve on kill line to mud pumps. Tested top drive IBOP and floor safety valves. All of the tests other than the annular were 250 psi low and 3500 psi high, held 5 minutes and charted. Tested gas alarms. Tested accumulator. Rig down testing equipment. Set FMC wear bushing. Blow down the choke manifold. Pre job safety meeting on picking up BHA #2 (GeoPilot). Pickup/ Make up BHA # 2 to 100', upload Sperry Sun MWD, shallow test MWD. continue BHA #2, PJSM, Load nuke sources, con't working BHA #2, pickup singles of 5" drill pipe from the pipe shed to 1913'. All of BHA #2 in the hole. 00:00 08:30 8.50 0 0 SURFA( DRILL PULD P Continue to pickup and rabbit 5" "S" and "G" drill pipe to 2.85 ". Stand back in the derrick. A total of 275 jts picked up. 08:30 10:15 1.75 0 0 SURFA( DRILL NUND P Finish nippling up BOPE: Install bell nipple, hook up flow line. Pickup Sperry Sun Geo -Span to the rig floor. 10:15 12:00 1.75 0 0 SURFA( DRILL SLPC P Slip and cut 60' of 1 -3/8" drilling line. Service top drive. Adjust brakes on the drawworks. 12:00 12:15 0.25 0 0 SURFA( DRILL RURD P RU to test BOPE. Install lower test plug. 12:15 12:30 0.25 SURFA( DRILL SFTY P Pre job safety meeting prior to testing BOPE Page 7 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 17:00 4.50 0 0 SURFA( DRILL BOPE P Test BOPE: Witness of test by AOGCC inspector John Crisp. Test w/ 5" test joint: Annular to 250 psi low and 2500 psi high. Test upper pipe (3 -1/2" x 6" variable), lower pipe (3 -1/2" x 6" variable) and blinds, inside and outside kill and choke valves, all valves in the choke manifold and 4" valve on kill line to mud pumps. Tested top drive IBOP and floor safety valves. All of the tests other than the annular were 250 psi low and 3500 psi high, held 5 minutes and charted. Tested gas alarms. Tested accumulator. 17:00 17:30 0.50 0 0 SURFA( DRILL RURD P Rig down testing equipment. Set FMC wear bushing. Blow down the choke manifold. 17:30 17:45 0.25 0 0 SURFA( DRILL SFTY P Pre job safety meeting on Picking up BHA #2 (GeoPilot). 17:45 19:30 1.75 0 1,000 SURFA( DRILL PULD P Pickup/ Make up BHA # 2. 19:30 20:45 1.25 1,000 1,000 SURFA( DRILL PULD P Upload Sperry Sun MWD. 20:45 21:30 0.75 100 100 SURFA( DRILL DHEQ P Test Sperry Sun geoSpan skid to 3500 psi. Shallow test MWD- OK. Pumping 600 gpm w/ 1050 psi. 21:30 22:00 0.50 142 142 SURFA( DRILL PULD P Continue to Pick up/ Make up BHA # 2. 22:00 22:15 0.25 142 142 SURFA( DRILL SFTY P Pre job safety meeting on picking up nuke sources, 22:15 22:30 0.25 142 142 SURFA( DRILL PULD P Pick up, install sources, run in to 142'. 22:30 23:15 0.75 142 768 SURFA( DRILL PULD P Continue to Pick up/ Make up BHA # 2. All of 5" HWDP in the hole. String wt 114k w/ blocks. 23:15 00:00 0.75 768 1,913 SURFA( DRILL PULD P Continue with BHA # 2, picking up/ make up 34 joints of 5" drill pipe from the pipe shed, make up ghost reamer, then 2 more joints of 5" drill pipe. 10/24/2009 Fill pipe , test MWD and GeoPilot @ 1913', continue picking up 5" f/ the pipe shed to 3145', trip in a stand, make a top drive connection, wash to the top of cement (Q7 3285', circulate, PJSM, test casing to 3530 psi f/ 30 minutes (25 psi loss- good test), chart test, drill cement, wiper rubbers, float collar (3307'), cement, shoe (3380- 3382') (2387' TVD), rat hole to 3393', 20' of new hole to 3413', conduct FIT /LOT (9.6 MW applied pressure 1050 psi= 18.1 EMW. picked by excel spread) ( town will evaluate on Monday f/ final determination). Displace to new 9.6 ppg LSND mud, directional drill 9 -7/8" hole f/ 3413' to 4857' (2995' TVD). 00:00 00:15 0.25 1,913 1,913 SURFA( CEMEN• CIRC P Fill pipe, test MWD tools and GeoPilot. Pumping 610 gpm w/ 1675 psi 39% flow out. Good test. 00:15 01:45 1.50 1,913 3,145 SURFA( CEMEN" PULD P Continue picking up/ make up 39 joints of 5" drill pipe from the pipe shed. Page 8 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 02:00 0.25 3,145 3,285 SURFA( CEMEN" WASH P Trip in a stand f/ derrick to 3240', make a top drive connection and wash down from 3240' tagging stringers @ 3255'. Rotate 50 rpm w/ 9k ft Ibs of torque, pumping 750 gpm w/ 2750 psi to tag top of cement © 3285'. 02:00 02:15 0.25 3,285 3,285 SURFA( CEMEN" CIRC P Circulate prior to casing test. Circulate 750 gpm w/ 2700 psi. 02:15 02:30 0.25 3,285 3,240 SURFA( CEMEN"TRIP P Pull up, break off stand, blow down top drive. (bit @ 3240'). 02:30 02:45 0.25 3,240 3,240 SURFA( CEMEN" SFTY P Pre job safety meeting prior to casing test. Rig up to test casing. 02:45 03:30 0.75 3,240 3,240 SURFA( CEMEN" PRTS P Test 10 -3/4" 45.5 ppf L -80 BTC -m casing to 3530 psi, hold test f/ 30 minutes, chart test. Loss of 25 psi. Good test. Rig down casing testing equipment. 03:30 03:45 0.25 3,240 3,307 SURFA( CEMEN" COCF P Make up top drive. Drill cement f/ 3285' to wiper plugs on top of the Halliburton Sure Seal II float collar @ 3307'. Drill w/ 4 -6k weight on bit, rotating 80 rpm w/ 9k ft Ibs of torque, pumping 750 gpm w/ 2630 psi. 03:45 06:00 2.25 3,307 3,308 SURFA( CEMEN COCF P Drill wiper rubbers and float collar. Drill w/ 4 -18k weight on bit, rotating 60 -80 rpm w/ 9k ft Ibs of torque, pumping 750 gpm w/ 2630 psi. 06:00 07:15 1.25 3,308 3,393 SURFA( CEMEN" COCF P Drill cement f/ 3308' to float shoe @ 3380 to 3382', clean out rat hole to 3393'. Drill w/ 2 to 5k weight on bit, rotating 80 rpm w/ 9k ft Ibs of torque, pumping 750 gpm w/ 2630 psi. 07:15 07:30 0.25 3,393 3,413 SURFA( DRILL DDRL P Drill 20' of new hole f/ 3393' to 380 to 3413' (2397' TVD). Drill w/ 5k weight on bit, rotating 80 rpm w/ 9k ft Ibs of torque, pumping 750 gpm w/ 2630 psi. ADT .14 hr. 07:30 08:15 0.75 3,413 3,413 SURFA( DRILL CIRC P Circulate and condition mud prior to LOT /FIT. Pumping 750 gpm w/ 2530 psi. Rotate 80 rpm w/ 10k ft Ibs of torque. Observe well f/ flow - static. 08:15 08:30 0.25 3,413 3,413 SURFA( DRILL SFTY P Pre job safety meeting on rig up f/ FIT /LOT. Break off top drive, blow down topdrive, rig up f/ testing. 08:30 08:45 0.25 3,413 3,413 SURFA( DRILL LOT P Perform FIT test._ Casing shoe © 3383' (2397' TVD) using 9.6 ppg MW, with 1050 applied pressure. Excel spread sheet picked 18.1 ppg. Will be evaluated in town monday f/ final determination. On 10 -29 -09 results of evaluation was a 16.6 ppg LOT w/ leak off at 870 psi. Page 9of58 • Time Logs Date From To ' Dur S. Depth E. Depth Phase ; Code Subcode T Comment 08:45 12:00 3.25 3,413 3,627 INTRMI DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 3413' to 3627' (2476' TVD). Actual drilling time 1.28 hrs. ECD's 10.31 ppg. Drilled w/ 5 -14k weight on bit, rotating 70 to 150 rpm, torque on bottom 10k ft Ibs, torque off bottom 7.5k ft Ibs. Pumping 800 gpm w/ 2000 psi. PU wt 153k, SOW 112k, Rot wt 130k. Jar* 162010029= 70.13 hrs. Note: Displaced to 9.6 ppg new LSND after LOT. 12:00 00:00 12.00 3,627 4,857 INTRMI DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 3627' to 4857' (2995' TVD). Actual drilling time 7.72 hrs. ECD's 10.3 to 10.7 ppg. Drilled w/ 5 to 30k weight on bit, rotating 50 to150 rpm, torque on bottom 8.5 to 10k ft Ibs, torque off bottom 6.5 to 7.5k ft Ibs. Pumping 600 -800 gpm w/ 1530 to 2440 psi. PU wt 144 to 160k, SOW 112 to 125k, Rot wt 130 to 139k. Jar # 1621 0029= 77.85hrs. Note: 275 bbl whole mud dilution while drilling @ 4750'. 40 bbl High vis /nutplug sweeps pumped at 3815', 4200', 4480' and 4756'. 10/25/2009 _Continue to directional drill 9 -7/8" hole f/ 4857' to 6855' (3765' TVD). repair # 2 mud pump (weld up 2 -1/4" crack on sweep 90 below pulsation dampner), backream f/ 6855' to 6465' while making repair, service the top drive, Ream back in the hole from 6465' to 6855', test mud line to 3500 psi -ok. Pumping 800 gpm w/ 2820 psi MWD not working, trouble shoot MWD w/ no success. Flow check well- static. Pull out of the hole 5 stands to 6380', monitor on trip tank. 5th stand incorrect fill. Will backream @ 750 gpm after midnight. 00:00 12:00 12.00 4,857 6,189 INTRM1 DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 4857' to 6189' (3514' TVD). Actual drilling time 7.25 hrs. ECD's 10.3 to 10.84 ppg. Drilled w/ 5 to 20k weight on bit, rotating 90 to170 rpm, torque on bottom 9.5 to 11.5k ft Ibs, torque off bottom 7.5 to 8.5k ft Ibs. Pumping 500 -800 gpm w/ 1140 to 3090 psi. PU wt 165 to 180k, SOW 123 to 133k, Rot wt 140 to 148k. Jar # 1621 0029= 85.1 hrs. Note: 275 bbl whole mud dilution while drilling @ 5800'. 40 bbl High vis /nutplug sweep pumped at 5143'. Page 10of58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:15 6.25 6,189 6,855 INTRMI DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 6189' to 6855' (3765' TVD). Actual drilling time 3.14 hrs. ECD's 10.83 to 10.98 ppg. Drilled w/ 8 to 17k weight on bit, rotating 170 rpm, torque on bottom 11 to 11.5k ft Ibs, torque off bottom 7.5 to 8.0k ft Ibs. Pumping 800 gpm w/ 2780 to 3090 psi. PU wt 165 to 170k, SOW 133 to 138k, Rot wt 148 to 152k. Jar # 1621 0029= 88.24hrs. Note: 275 bbl whole mud dilution while drilling @ 6400' and 6760'. 40 bbl High vis /nutplug sweeps pumped at 6290' and 6560'. 18:15 20:00 1.75 6,855 6,570 INTRM1 DRILL RGRP T Stand back a stand. Work on repair of 2 -1/4" crack on sweep 90 coming off of mud pump #2. While repairing pump: Backream slow (3 -4 ft/min), standing back a stand every 30 to 45 minutes. Pumping with # 1 mud pump at 110 spm (462 gpm w/ 1130 psi- 28% flow out. Rotate 100 rpm w/ 8 -9k ft Ibs of torque. 20:00 20:30 0.50 6,570 6,570 INTRM1 DRILL SVRG P Service rig and top drive. 20:30 20:45 0.25 6,570 6,465 INTRMI DRILL RGRP T Continue to work on repair of 2 -1/4" crack on sweep 90 coming off of mud pump #2. While repairing pump: Backream slow (3-4 ft/min), standing back a stand every 30 to 45 minutes. Pumping with # 1 mud pump at 110 spm (462 gpm w/ 1130 psi- 28% flow out. Rotate 100 rpm w/ 8 -9k ft Ibs of torque. 20:45 21:15 0.50 6,465 6,855 INTRM1 DRILL REAM T Ream back in the hole. Pumping 110 spm (462 gpm) w/ 1100 psi. Rotate 100 rpm w/ 8k ft Ibs of torque. 21:15 21:30 0.25 6,855 6,855 INTRM1 DRILL PRTS T Test mud line to 3500 psi- OK. 21:30 23:30 2.00 6,855 6,855 INTRM1 DRILL CIRC T Trouble shoot MWD. No pulse - Dead. No communication. Had some trouble during day acquiring surveys. 23:30 00:00 0.50 6,855 6,380 INTRM1 DRILL TRIP T Flow check- static. Pull out of the hole on the trip tank. 5th stand incorrect- no fill. Pulling 6th - swabbing. WiII backream after midnght, pumping 750 gpm w/ 2650 psi. PU wt 170k, SO wt 140k. Page 11 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/26/2009 24 hr S umma ry Tripping f/ Sperry Sun MWD failure: Backream f/ 6475' to 5333', pull out from 5333' to 3335', observe well- static, circulate 3 bottom's up inside of casing, attempt to pull out of the hole f/ 3335' to 2955', improper hole fill, observe well - static, continue to pump out of the hole f/ 2955' to 769', continue pulling out of the hole to 112', PJSM, remove nuke sources, down load MWD, check oil in the geoPilot, check the bit- no wear, replace the pulsar, attempt to upload- no good, Change out SIM (electrical connection)- no good, change out CNT /SLD nuke tool, upload MWD, make up BHA #3 to 112', pulse test MWD- good, PJSM, then load nuke sources, continue to make up BHA #3, run in the hole to 2990', fill pipe- confirm MWD working, continue running in the hole to 4759', fill pipe, continue to run in the hole to 6660', PJSM, fill pipe, circulate bottom's up while dumping ( dumped 336 bbls while circulating- had dumped 192 bbls while tripping) and diluting( added 550 bbls of new mud) , make connections and ream f/ 6660' to 6855', ready to drill 9 -7/8" hole w/ geoPilot at midnight. 00:00 02:15 2.25 6,380 5,333 INTRMI DRILL REAM T Backream f/ 6475' to 5333', pumping 750 gpm w/ 2650 psi. Rotate 120 rpm w/ 9k ft lbs of torque. PU wt 165k, SO wt 125k, rot wt 143k. Continue to trip f/ Sperry Sun MWD failure. 02:15 03:45 1.50 5,333 3,335 INTRM1 DRILL TRIP T Pull out of the hole f/ 5333' to 3335' (10 -3/4" shoe @ 3382'), monitor on the trip tank. 03:45 04:00 0.25 3,335 3,335 INTRMI DRILL OWFF T Observe well at 3335'- static. 04:00 05:15 1.25 3,335 3,335 INTRM1 DRILL CIRC T Circulate while inside of casing at 3335'. Pumping 750 gpm w/ 2340 psi, rotate 70 rpm w/ 6500 ft lbs of torque. 05:15 06:00 0.75 3,335 2,955 INTRM1 DRILL TRIP T Attempt to pull out of the hole, monitoring the well on the trip tank f/ 3335' to 2955'. Improper hole fill. 06:00 06:15 0.25 2,955 2,955 INTRMI DRILL OWFF T Observe well at 2955'- static. 06:15 09:15 3.00 2,955 769 INTRMI DRILL TRIP T Continue to pump out of the hole f/ 2955' to 769'. Pumping 378 gpm (90 spm) w/ 540 psi. Layed down both ghost reamers. 09:15 11:30 2.25 769 143 INTRMI DRILL TRIP T Continue to pull out of the hole f/ 769' to 143'. 11:30 11:45 0.25 112 143 INTRMI DRILL SFTY T Pre job safety meeting on removing Sperry Sun nuke sources. 11:45 12:00 0.25 1,430 95 INTRM1 DRILL OTHR T Remove nuke sources. 12:00 13:00 1.00 95 0 INTRMI DRILL OTHR T Down load Sperry Sun MWD, check oil in the GeoPilot (TL 129), check bit. 13:00 13:45 0.75 0 104 INTRM1 DRILL OTHR T Replace pulsar. 13:45 14:15 0.50 104 104 INTRM1 DRILL OTHR T Plug in- attempt to upload MWD- No Good. 14:15 14:30 0.25 104 104 INTRM1 DRILL PULD T Change SIM hanger (electrical fitting) in MWD. 14:30 15:30 1.00 104 81 INTRM1 DRILL PULD T Lay down hange off collar. change out Sperry Sun CNT /SLD (Nuke tool) 15:30 16:15 0.75 81 105 INTRMI DRILL OTHR T Plug in, then upload MWD. 16:15 16:30 0.25 105 112 INTRMI DRILL PULD T Pick up /make up stabilizer and float sub. 16:30 16:45 0.25 112 112 INTRM1 DRILL DHEQ T Pulse test MWD. Pumping 600 gpm w/ 980 psi. Good test. Blow down the top drive. Page 12 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 17:00 0.25 112 112 INTRMI DRILL SFTY T Pre job safety meeting on loading nuke sources. 17:00 17:30 0.50 112 112 INTRMI DRILL OTHR T Load sources. 17:30 18:45 1.25 112 1,914 INTRMI DRILL PULD T Make up stand of non mag collars, continue to make up BHA #3. 18:45 19:30 0.75 1,914 2,990 INTRMI DRILL TRIP T Run in the hole w/ BHA #3 on 5" drill pipe f/ 1914' to 2990'. 19:30 19:45 0.25 2,990 2,990 INTRMI DRILL CIRC T Fill pipe, confirm all componenets working. Pumping 650 gpm w/ 1800 psi. Blow down the top drive. 19:45 20:45 1.00 2,990 4,759 INTRMI DRILL TRIP T Run in the hole w/ BHA #3 on 5" drill pipe f/ 2990' to 4759'. 20:45 21:15 0.50 4,759 4,759 INTRMI DRILL CIRC T Fill pipe. Blow down the top drive. 21:15 22:00 0.75 4,759 6,660 INTRM1 DRILL TRIP T Run in the hole w/ BHA #3 on 5" drill pipe f/ 4759' to 6660'. PU wt 160k, SO wt 123k. 22:00 22:15 0.25 6,855 INTRM1 DRILL SFTY T Pre job safety meeting on mud displacement/ mud swap. 22:15 22:30 0.25 6,660 6,660 INTRMI DRILL CIRC T Fill pipe @ 6660', break circulation. 22:30 23:30 1.00 6,660 6,660 INTRM1 DRILL CIRC T Circulate two bottom's up starting at 750 gpm w/ 2790 psi ECD's 10.82. Final circulating rate of 700 gpm w/ 2100 psi, ECD's 10.3 ppg. Circulated a bottom's up, pumped a 40 bbl high vis sweep, Sweep brought up 100% increase in cuttings. Dumped 336 bbls of mud from the hole while circulating. While tripping we dumped 192 bbls of mud. Total new mud added was 550 bbls. Initial PU wt 160k, SO wt 145k w/o pumps. Rotating wt w/ pumps on 145k. Reciprocate f/ 6660' to 6570'. Rotate 120 rpm w/ 9.5k ft lbs of torque. 23:30 00:00 0.50 6,660 6,855 INTRM1 DRILL REAM T Make a connection, then ream in the hole from 6660' to 6855'. Pumping 750 gpm w/ 2570 psi. Rotate 120 rpm w/ 10k ft Ibs of torque. 10/27/2009 Directional drill 9 -7/8" hole f/ 6855' to 9913' (4964' TVD), Repair # 2 mud pump ( Center cylinder -- cracked fluid end) Circulate w/ # 1 @ 400 to 435 gpm w/ 930 to 1050 psi. Backream f/ 9913' to 9468'. Pulling a stand every 30 min (3' -4' /min). Rotate 90 to 100 rpm w/ 10.5k ft lbs of torque. Page 13 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 6,855 8,473 INTRMI DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 6855' to 8473' (4396' TVD). Actual drilling time 6.63 hrs. ECD's 10.41 to 10.74 ppg. Drilled w/ 10 -22k weight on bit, rotating 170 rpm, torque on bottom 10.5 to 13.5k ft Ibs, torque off bottom 8.0 to 9k ft Ibs. Pumping 800 gpm w/ 2980 to 3150 psi. PUwt170to 185k, SOW 138 to 145k, Rot wt 155 to 164k. Jar # 1621 0029= 94.87hrs. Note: 275 bbl whole mud dilution while drilling @ 7901'. 40 bbl High vis /nutplug sweeps pumped at 7521'. 12:00 20:30 8.50 8,473 9,913 INTRM1 DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 8473' to 9913' (4964' TVD). Actual drilling time 4.24 hrs. ECD's 10.66 to 10.97 ppg. Drilled w/ 17 -25k weight on bit, rotating 170 rpm, torque on bottom 13.5 to 15k ft Ibs, torque off bottom 9.0 to 10k ft Ibs. Pumping 800 gpm w/ 3070 to 3300 psi. PU wt 188 to 200k, SOW 145 to 153k, Rot wt 166 to 175k. Jar # 1621 0029= 99.11 hrs. Note: 275 bbl whole mud dilution while drilling @ 8663' and 9710'. 40 bbl High vis /nutplug sweeps pumped at 9145'. 20:30 00:00 3.50 9,913 9,468 INTRMI DRILL RGRP T Repair# 2 mud pump ( Center cylinder -- cracked fluid end) Circulate w/ # 1 @ 400 to 435 gpm w/ 930 to 1050 psi. Backream f/ 9913' to 9468'. Pulling a stand every 30 min (3'-4' /min). Rotate 90 to 100 rpm w/ 10.5k ft Ibs of torque. 10/28/2009 Repair # 2 mud pump ( Center cylinder -- cracked fluid end) (Change out fluid end). While working on mud pump #2, Circulate w/ # 1 @ 400 to 435 gpm w/ 1050 to 880 psi. Backream f/ 9468' to 8470' (note: upper ghost reamer past last trip point © 6855'. Pulling a stand every 30 min (3'-4' /min). Rotate 90 to 100 rpm w/ 10.5 to 12k ft Ibs of torque. Monitor well @ 8470' -ok. Trip in the hole to 9854'. Test mud pump # 2 to 3500 psi -ok. Precautionary ream f/ 9854' to 9913', directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 9913' to 11993 (5790' TVD). 00:00 06:00 6.00 9,468 8,660 INTRM1 DRILL RGRP T Repair # 2 mud pump ( Center cylinder -- cracked fluid end). Change out fluid end. Circulate w/ # 1 @ 400 to 435 gpm w/ 930 to 1050 psi. Backream f/ 9468' to 8660'. Pulling a stand every 30 min (3'-4' /min). Rotate 90 to 100 rpm w/ 10.5 to 12k ft Ibs of torque. Page 14of58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code ` Subcode T Comment 06:00 08:00 2.00 8,660 8,470 INTRM1 DRILL RGRP T Continue to repair # 2 mud pump Center cylinder -- cracked fluid end). Change out fluid end. Circulate w/ # 1 @ 430 gpm w/ 880 psi. Backream f/ 8660' to 8470'. Pulling a stand every 30 min (3'-4' /min). Rotate 100 rpm w/ 12k ft Ibs of torque. 08:00 08:15 0.25 8 470 8 470 INTRMI DRILL RGRP T Continue to repair # 2 mud um 0 p pump Center cylinder -- cracked fluid end). Change out fluid end. Monitor well. 08:15 09:15 1.00 8,470 9,854 INTRM1 DRILL TRIP T Trip in the hole, using trip tank. Run in f/ 8470' to 9854'. 09:15 09:30 0.25 9,854 9,854 INTRMI DRILL PRTS T Fill mud pump #2 with mud. Test to 3500 psi. OK. 09:30 10:00 0.50 9,854 9,913 INTRM1 DRILL REAM T Precautionary ream in the hole from 9854' to 9913'. Pumping 750 gpm w/ 2530 psi. Rotate 130 rpm w/ 10k ft Ibs of torque. 10:00 12:00 2.00 9,913 10,154 INTRM1 DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 9913' to 10154' (5061' TVD). Actual drilling time .75 hrs. ECD's 10.43 ppg. Drilled w/ 18 -23k weight on bit, rotating 170 rpm, torque on bottom 15.5k ft Ibs, torque off bottom 10k ft Ibs. Pumping 800 gpm w/ 3040 psi. PU wt 202k, SOW 155 k, Rot wt 178k. Jar # 1621 0029= 99.86 hrs. 12:00 00:00 12.00 10,154 11,993 INTRM1 DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 10154' to 11993' (5792' TVD). Actual drilling time 5.75 hrs. ECD's 11.2 ppg. Drilled w/ 20 -25k weight on bit, rotating 170 rpm, torque on bottom 15.5 to 17.5k ft Ibs, torque off bottom 10 to 11k ft Ibs. Pumping 800 gpm w/ 3040 to 3480 psi. PU wt 202 to 225k, SOW 155 to 160 k, Rot wt 178 to 189k. Jar # 1621 0029= 105.61 hrs. Note: 275 bbl whole mud dilution while drilling @ 10414' and 11040'. 10/29/2009 Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 11993' to 14906' (6932.82' TVD). Backream pumping 420 gpm w/ 1450 psi f/ 14906' to 14593' while repair #1 mud pump (discharge screen, downstream side- flange washed- replace discharge screen. Page 15 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 11,993 12,855 INTRM1 DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 11993' to 12855' (6124' TVD). Actual drilling time 3.76 hrs. ECD's 11.04 ppg. Drilled w/ 15 to 30k weight on bit, rotating 170 rpm, torque on bottom 116 to 18k ft Ibs, torque off bottom 11 to 11.5k ft Ibs. Pumping 800 gpm w/ 3140 to 3530 psi. PU wt 225 to 230k, SOW 160 to 164 k, Rot wt 189 to 196k. Jar # 1621 0029= 109.37 hrs. Note: 275 bbl whole mud dilution while drilling @ 12368'. 06:00 12:00 6.00 12,855 13,662 INTRM1 DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 12855' to 13662' (6439' TVD). Actual drilling time 2.63 hrs. ECD's 10.8 ppg. Drilled w/ 15 to 30k weight on bit, rotating 170 rpm, torque on bottom 17 to 21k ft Ibs, torque off bottom 13.5 to 16k ft Ibs. Pumping 800 gpm w/ 3390 to 3270 psi. PU wt 238 to 250k, SOW 160 to 165 k, Rot wt 189 to 204k. Jar # 1621 0029= 112 hrs. Note: 275 bbl whole mud dilution while drilling @ 13000'. 12:00 18:00 6.00 13,662 14,637 INTRM1 DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 13622' to 14637' (6826' TVD). Actual drilling time 3.74 hrs. ECD's 10.8 ppg. Drilled w/ 15 to 30k weight on bit, rotating 160 -150 rpm, torque on bottom 20 to 22k ft Ibs, torque off bottom 16.5 to 18k ft Ibs. Pumping 800 gpm w/ 3270 to 3890 psi. PU wt 250 to 280k, SOW 165 to 160 k, Rot wt 200 to 213k. Jar # 1621 0029= 115.74 hrs. Note: 275 bbl whole mud dilution while drilling @ 13875'. For weight up: 550 bbl 11ppg spike fluid, and 140 bbl LSND w/ 36% inhibycol added starting at 14150' Page 16 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:00 3.00 14,637 14,906 INTRM1 DRILL DDRL P Directional drill 9 -7/8" intermediate hole w/ Sperry Sun GeoPilot (ser # TL129) from 14637' to 14906' (6932' TVD). Actual drilling time 1.57 hrs. ECD's 11.4 to 11.87 ppg. Drilled w/ 15 to 23k weight on bit, rotating 155 to 170 rpm, torque on bottom 22 to 20.5k ft Ibs, torque off bottom 18 to 15k ft lbs. Pumping 750 to 7800 gpm w/ 3670 to 3900 psi. PU wt 270k, SO wt 170 k, Rot wt 215k. Jar # 1621 0029= 117.31 hrs. 21:00 21:15 0.25 14,906 14,906 INTRM1 DRILL RGRP T Leak on #1 mud pump (Downstram side of discharge screen to vibrator hose- 5 -1/8" 5m flange washed). Clean up 21:15 00:00 2.75 14,906 14,593 INTRMI DRILL RGRP T Clean up spill of less than 5 gallons in pump room floor. Remove flange from # 1 mud pump, determine what needs to be changed out (changed out the complete discharge screen). Circulate with #2 mud pump @ 430 gpm with 1450 psi. Rotate 100 rpm w/ 17.5k ft lbs of torque. Backream from 14906' to 14593', while working on #1 mud pump. 10/30/2009 Continue to backream pumping 420 gpm w/ 1450 psi f/ 14593' to 14406' while repairing #1 mud pump (discharge screen, downstream side- flange washed- replace discharge screen. Pressure test pump #1 to V 4000 psi- OK. Circulate 1/2 bottom's up @ 777 gpm w/ 3900 psi, monitor ECD's (11.21 ppg), Monitor well- static, run in the hole from 14500' to 14872', continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 6 {yam 14906' to 15662' ( 7228' TVD), Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 15523' to 15662' A \l' (7228' TVD), Pump pressure decreased from 3830 psi to 3770 psi. Picked up off bottom from 15662' to f 15650'. Monitor well while pumping 725 gpm w/ 3770 psi. Gained 10 to 15 bbls. Shut in well @ 1319 hrs Notified town drilling engineer, drilling manager, pad operator, and AOGCC of well control incident. Circulate through choke. Pumping 250 gpm w/ 990 psi. Circulated surface to surface= (14000 strokes). Maintain 11.48 ECD's. Shut down and monitor well f/ 30 minutes. Initial drill pipe pressure 190 psi; after 15 minutes, stable at 260 psi, stayed 260 psi. Initial csg pressure 210 psi, final 230 psi. Kill wt mud appears to be 11.3 ppg. Note: At 2200 hrs: Rotate drill string with annular closed: 26k ft lbs to break free, then 18 k ft Ibs of torque to rotate freely. Circulate and weight up from 10.5 ppg to 10.8 ppg while circulating through the choke. Maintain 11.48 to 11.52 equivalent mud weight w/ Sperry Sun PWD tools. Pumping 65 to 66 spm (275 to 277 gpm) w/ 980 to 1010 psi. Adding dyna red fine and /or nut plug fine 2 sx/5 min (24 sx per hour). Final 65 spm (273 gpm) w/ 910 psi on drill pipe, 20 psi on csg. Mud weight is 10.8 ppg to surface at midnight. Note: At midnight: Rotate drill string with annular closed: 26k ft Ibs to break free, then 18 k ft lbs of torque to rotate freely. 00:00 04:00 4.00 14,593 14,406 INTRMI DRILL REAM T Continue to backream pumping 420 gpm w/ 1450 psi f/ 14593' to 14406' while repairing #1 mud pump (discharge screen, downstream side - flange washed- replace discharge screen. 04:00 04:30 0.50 14,406 14,500 INTRMI DRILL CIRC T Circulate 1/2 bottom's up monitoring PWD- - ECD's, pumping 777 gpm w/ 3900 psi. ECD's 11.21 ppg. 04:30 04:45 0.25 14,500 14,500 INTRMI DRILL OWFF T Monitor well- static, Page 17 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 05:45 1.00 14,500 14,872 INTRM1 DRILL TRIP T Trip in the hole from 14500' to 14872'. The hole is in good shape. 05:45 06:45 1.00 14,872 14,906 INTRM1 DRILL REAM T Obtain parameters, precautionary ream in the hole from 14872' to 14906'. Rotate 125 rpm w/ 17k ft Ibs of torque. Pumping 700 to 777 gpm w/ 3000' to 3900 psi. 06:45 08:00 1.25 14,906 15,020 INTRM1 DRILL DDRL P Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 14906' to 15020' (6977' TVD). Actual drilling time .73 hrs. ECD's 10.3 ppg. Drilled w/ 15 to 30k weight on bit, rotating 180 rpm, torque on bottom 22k ft Ibs, torque off bottom 18k ft lbs. Pumping 777 gpm w/ 3900 psi. PU wt 270k, SO wt 170k, Rot wt 215k. Jar # 1621 0029= 118.04 hrs. 08:00 14:00 6.00 15,020 15,523 INTRM1 DRILL DDRL P Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 15020' to 15523' (7174' TVD). Actual drilling time 3.47 hrs. ECD's 11.56 ppg. Drilled w/ 15 to 25k weight on bit, rotating 155 rpm, torque on bottom 21k ft Ibs, torque off bottom 16k ft lbs. Pumping 735 gpm w/ 3850 psi. PU wt 284k, SO wt 165k, Rot wt 219 k. Jar # 1621 0029= 121.51 hrs. Note: Geologist pick Kuparuk C @ 15488' (7108' SStvd), LCU @ 15502' (7113' SStvd) 14:00 15:00 1.00 15,523 15,662 INTRM1 DRILL DDRL P Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 15523' to 15662' (7228' TVD). Actual drilling time 1.13 hrs. ECD's 11.56 to 11.47 ppg. Drilled w/ 10 to 15k weight on bit, rotating 150 rpm, torque on bottom 23k ft Ibs, torque off bottom 17k ft Ibs. Pumping 725 gpm w/ 3830 psi. PU wt 290k, SO wt 165k, Rot wt 220k. Jar # 1621 0029= 122.64 hrs. 15:00 15:15 0.25 15,662 15,650 INTRM1 DRILL OWFF T Pump pressure decreased from 3830 psi to 3770 psi. Picked up off bottom from 15662' to 15650'. Monitor well while pumping 725 gpm w/ 3770 psi. Gained 10 to 15 bbls. Shut in well @ 1319 hrs. 15:15 19:30 4.25 15,650 15,650 INTRM1 DRILL CIRC T Notified town drilling engineer (Nina Anderson), drilling manager (Chip Alvord), pad operator, and AOGCC (Chuck Sheve) of well control incident. Circulate through choke. Pumping 250 gpm w/ 990 psi. Circulated surface to surface= (14000 strokes). Maintain 11.48 ECD's. Page 18 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:00 0.50 15,650 15,650 INTRM1 DRILL OWFF T Shut down and monitor well f/ 30 minutes. Initial drill pipe pressure 190 psi; after 15 minutes, stable at 260 psi, stayed 260 psi. Initial csg pressure 210 psi, final 230 psi. Kill wt mud appears to be 11.3 ppg. Note: Rotate drill string with annular closed: 26k ft Ibs to break free, then 18 k ft Ibs of torque to rotate freely. 20:00 00:00 4.00 15,650 15,650 INTRM1 DRILL CIRC T Circulate and weight up from 10.5 ppg to 10.8 ppg while circulating through the choke. Maintain 11.48 to 11.52 equivalent mud weight w/ Sperry Sun PWD tools. Pumping 65 to 66 spm (275 to 277 gpm) w/ 980 to 1010 psi. Adding dyna red fine and /or nut plug fine 2 sx/5 min (24 sx per hour). Final 65 spm (273 gpm) w/ 910 psi on drill pipe, 20 psi on csg. Mud weight is 10.8 ppg to surface at midnight. Note: Rotate drill string with annular closed: 26k ft Ibs to break free, then 18 k ft Ibs of torque to rotate freely. 10/31/2009 Shut down and monitor well f/ 30 minutes. Initial drill pipe pressure 60 psi; after 15 minutes, stable at 120 psi, stayed 120 psi. Initial csg pressure 60 psi, final 150 psi. Kill wt mud appears to be 11.2 to 11.3 ppg. Circulate and weight up from 10.8 ppg to 11.2 ppg while circulating through the choke. Maintain 11.48 to 11.52 equivalent mud weight w/ Sperry Sun PWD tools. Pumping 65 to 66 spm (275 to 277 gpm) w/ 920 to 930 psi w/ wide open choke at almost surface to surface. Adding dyna red fine and /or nut plug fine 2 sx/5 min (24 sx per hour). Final 66 spm (273 gpm) w/ 920 psi on drill pipe, 0 psi on csg. Mud weight @ shakers was 11.1 ppg at 0630 hrs. Monitor well: Initial and final dp pressure was 30 psi. Initial csg pressure was o, final 70 psi. Continue to circulate and weight up to 11.2 ppg, taking returns through the choke. Pumping 275 gpm w/ 920 psi - choke side open. Monitor well: Initial and final dp pressure was 30 psi. Initial and final casing pressure was 0 psi. Note: Rotate drill string with annular closed: 24k ft Ibs to break free, then 18 k ft Ibs of torque to rotate freely every 2 hours. Open choke, open annular @ 0830 hrs, rotate pipe freely w/ 17.5k ft Ibs of torque. Start circulating 315 gpm w/ 1180 psi -ECD's 11.75 ppg. Rotate 50 rpm w/ 17.5k ft Ibs of torque. Continue circulating and weight up from 11.2 ppg to 11.5 ppg. Pumping 378 gpm w/ 1480 psi, rotate 70 rpm w/ 19.5k ft Ibs of torque. Monitor well: Slight flow, gained less than a bbl. Continue to circulate 11.5 ppg mud, then weight up to 11.8 ppg. Initial circ rate of 350 gpm w/ 1350 psi- Final rate of 269 gpm w/ 1060 psi- ECD's 12.46 ppg. Rotate 70 rpm w/ 19.5k ft Ibs of torque. Obtain slow pump rates w/ 11.8 ppg mud. Monitor well: Slight losses. Circulate bottom's up pumping 378 gpm w/ 1685 psi - -12.52 ppg ECD's. Adding dyna red fine and /or nut plug fine 2 sx/10 min (12 sx per hour). I I Page 19of58 • Time Logs Date From To " Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:15 0.25 15,650 INTRMI DRILL CIRC T Circulate and weight up from 10.5 ppg to 10.8 ppg while circulating through the choke. Maintain 11.48 to 11.52 equivalent mud weight w/ Sperry Sun PWD tools. Pumping 65 to 66 spm (275 to 277 gpm) w/ 980 to 1010 psi. Adding dyna red fine and /or nut plug fine 2 sx/5 min (24 sx per hour). Final 65 spm (273 gpm) w/ 910 psi on drill pipe, 20 psi on csg. Mud weight is 10.8 ppg to surface at midnight. Note: Rotate drill string with annular closed: 26k ft Ibs to break free, then 18 k ft Ibs of torque to rotate freely. 00:15 00:45 0.50 15,650 15,650 INTRMI DRILL OWFF T Shut down and monitor well f/ 30 minutes. Initial drill pipe pressure 60 psi; after 15 minutes, stable at 120 psi, stayed 120 psi. Initial csg pressure 60 psi, final 150 psi. Kill wt mud appears to be 11.2 to 11.3 ppg. 00:45 06:30 5.75 15,650 15,650 INTRM1 DRILL CIRC T Circulate and weight up from 10.8 ppg to 11.2 ppg while circulating through the choke. Maintain 11.48 to 11.52 equivalent mud weight w/ Sperry Sun PWD tools. Pumping 65 to 66 spm (275 to 277 gpm) w/ 910 to 920 psi. Choke wide open from 0422 hrs (just prior to surface to surface strokes pumped), with ECD's 11.7 ppg. Adding dyna red fine and /or nut plug fine 2 sx/5 min (24 sx per hour). Final rate of 65 spm (273 gpm) w/ 930 psi on drill pipe, 0 psi on csg, ECD's 11.8 ppg. Mud weight is 11.1 ppg to surface. Pumped a total of 22388 strokes. Note: Rotate drill string with annular closed: 26k ft Ibs to break free, then 18 k ft Ibs of torque to rotate freely. 06:30 07:00 0.50 15,650 15,650 INTRM1 DRILL OWFF T Shut down and monitor well f/ 30 minutes. Initial drill pipe pressure 30 psi; stayed 30 psi. Initial csg pressure 0 psi, final 70 psi. Kill wt mud still appears to be 11.2 to 11.3 PP9• Page 20 of 58 • Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 07:00 08:15 1.25 15,650 15,650 INTRM1 DRILL CIRC T Continue to circulate and weight up from 10.8 ppg to 11.2 ppg while circulating through the choke. Maintain 11.48 to 11.52 equivalent mud weight w/ Sperry Sun PWD tools. Pumping 65 to 66 spm (275 to 277 gpm) w/ 920 to 930 psi with choke wide open at almost surface to surface strokes.. Adding dyna red fine and /or nut plug fine 2 sx/5 min (24 sx per hour). Final circulating rate of 64 spm (273 gpm) w/ 920 psi on drill pipe, ECD's 11.86 ppg, 0 psi on csg. Mud weight is 11.1+ ppg to surface at 0815 hrs. Note: Circulate a total of surface to surface plus a bottom's up+ (27414 strokes), still not 11.2 ppg to surface. Rotate drill string with annular closed: 24k ft lbs to break free, then 18 k ft Ibs of torque to rotate freely every 2 hrs. 08:15 08:30 0.25 15,650 15,650 INTRMI DRILL OWFF T Shut down and monitor well f/ 10 minutes. Initial drill pipe pressure 30 psi; stayed 30 psi. Initial csg pressure 0 psi, final 0 psi. Kill wt mud still appears to be 11.2 to 11.3 PP9• 08:30 11:30 3.00 15,650 15,650 INTRM1 DRILL CIRC T Open choke, open annular, rotate string freely w/ 17.5 k ft lbs. Circulate pumping 75 spm w/ 1180 psi, ECD's 11.75 to 11.76 ppg. Increase rate to 90 spm w/ 1480 psi. Rotate 50 rpm w/ gas breaking out at surface. 11:30 15:15 3.75 15,650 15,650 INTRM1 DRILL CIRC T Continue to circulate and weight up from 11.2 ppg to 11.5 ppg. Pumping 90 spm (378 gpm) w/ 1480 to 1415 psi . Rotate 70 rpm w/ 19.5k ft Ibs of torque. Adding dyna red fine and /or nut plug fine 2 sx/5 min (24 sx per hour). 15:15 15:30 0.25 15,650 15,650 INTRMI DRILL OWFF T Shut down and monitor well . Slight flow, gained less than a bbl. 15:30 18:45 3.25 15,650 15,650 INTRM1 DRILL CIRC T Continue to circulate 11.5 ppg. Initial pump rate of 90 spm (378 gpm) w/ 1530 psi . Final pump rate of 83 spm (349 gpm) w/ 1370 psi- ECD's 12.17 ppg. Rotate 60 rpm w/ 18.5k ft Ibs of torque. Adding dyna red fine and /or nut plug fine 2 sx/5 min (24 sx per hour). Page 21 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code - Subcode T Comment 18:45 22:15 3.50 15,650 15,650 INTRM1 DRILL CIRC T Continue to circulate and weight up from 11.5 ppg to 11.8 ppg. Initial pump rate of 83 spm (350 gpm) w/ 1350 psi . Rotate 70 rpm w/ 19.5k ft Ibs of torque. Final pump rate of 64 spm ( 269 gpm) w/ 1060 psi- ECD's 12.46 ppg. Adding dyna red fine and /or nut plug fine 2 sx/5 min (24 sx per hour). 22:15 22:45 0.50 15,650 15,650 INTRM1 DRILL OWFF T Obtain slow pump rates w/ 11.8 ppg MW. # 1 30 spm 520 psi, 40 spm 630 psi. # 2 30 spm 520 psi, 40 spm 630 psi. Shut down and monitor well . Slight losses. 22:45 00:00 1.25 15,650 15,650 INTRMI DRILL CIRC T Circulate bottom's up while staging pump rate up from 64 spm (269 gpm). Final rate at midnight 90 spm ( 378 gpm) w/ 1685 psi. ECD's 12.52 PPg• 11/01/2009 Circulate bottom's up w/ 11.8 ppg mud weight, pumping 378 gpm w/ 1685 psi - -12.52 ppg ECD's. Obtain slow pump rates, obtain flow % relative to flow rates. Ream f/ 15650' to bottom at 15662' pumping 625 to 630 gpm w/ 3850 psi— ECD's 12.64 ppg, rotating 90 rpm w/ 23.5k ft Ibs of torque. Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 15662' to 16525' (7513' TVD). Adding dyna red fine and /or nut plug fine 2 sx/10 min (12 sx per hour). Note: Diluted mud system w/ new 11.8 ppg mud while drilling at 16092' and again @ 16473'. Note: TD for 7 -5/8" intermediate casing was 16548' (7519' TVD) @ 0100 hrs 11/2/2009. 00:00 00:45 0.75 15,650 15,650 INTRM1 DRILL CIRC T Circulate bottom's up while staging pump rate up from 90 spm (378 gpm) w/ 1685 psi. ECD's 12.52 ppg. Final pump rate: 175 spm (630 gpm) w/ 3850 psi. ECD's 12.64 ppg. Adding dyna red fine and /or nut plug fine 2 sx /10 min (12 sx per hour). 00:45 01:00 0.25 15,650 15,662 INTRM1 DRILL REAM T Ream from 15650' to 15662'. 90 RPM w/ 23500 ft Ibs of torque. Pumping 630 gpm w/ 3850 psi- ECD's 12.64 PPg• 01:00 06:00 5.00 15,662 15,835 INTRMI DRILL DDRL P Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 15662' to 15835' (7296' TVD). Actual drilling time 3.53 hrs. ECD's 12.73 to 12.66 ppg. Drilled w/ 12 to 20k weight on bit, rotating 150 rpm, torque on bottom 24 to 26k ft Ibs, torque off bottom 21k ft Ibs. Pumping 630 gpm w/ 3830 psi- ECD's 12.66 ppg. Adding dyna red fine and /or nut plug fine 2 sx/10 min (12 sx per hour). PU wt 365k, SO wt 141k, Rot wt 215k. Jar # 1621 0029= 126.17 hrs. Page22of58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ; Comment 06:00 12:00 6.00 15,835 16,025 INTRM1 DRILL DDRL P Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 15835' to 16025' (7371' TVD). Actual drilling time 4.22 hrs. ECD's 12.66 to 12.62 ppg. Drilled w/ 12 to 20k weight on bit, rotating 150 rpm, torque on bottom 28.5k ft Ibs, torque off bottom 22.5k ft Ibs. Pumping 630 gpm w/ 3850 psi. Adding dyna red fine and /or nut plug fine 2 sx/10 min (12 sx per hour). PU wt 380k, SO wt 142k, Rot wt 220k. Jar # 1621 0029= 130.39 hrs. 12:00 18:00 6.00 16,025 16,298 INTRM1 DRILL DDRL P Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 16025' to 16298' (7462' TVD). Actual drilling time 4.74 hrs. ECD's 12.62 to 12.56 ppg. Drilled w/ 12 to 20k weight on bit, rotating 150 rpm, torque on bottom 28.5k ft Ibs, torque off bottom 22.5k ft Ibs. Pumping 625 gpm w/ 3850 psi. Adding dyna red fine and /or nut plug fine 2 sx/10 min (12 sx per hour). PU wt 385k, SO wt 150k, Rot wt 220k. Jar # 1621 0029= 135.13 hrs. Note: Diluted mud system w/ 215 bbls of 11.8 ppg LSND mud while drilling @ 16085'. 18:00 00:00 6.00 16,298 16,525 INTRM1 DRILL DDRL P Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 16298' to 16525' (7513' TVD). Actual drilling time 4.81 hrs. ECD's 12.56 to 12.7 ppg. Drilled w/ 15 to 20k weight on bit, rotating 140 rpm, torque on bottom 25.5k ft Ibs, torque off bottom 23.5k ft Ibs. Pumping 625 gpm w/ 3880 psi. Adding dyna red fine and /or nut plug fine 2 sx/10 min (12 sx per hour). PU wt 370k, SO wt 150k, Rot wt 220k. Jar # 1621 0029= 139.94 hrs. Note: Diluted mud system w/ 275 bbls of 11.8 ppg LSND mud while drilling @ 16473'. 11/02/2009 Continue to directional drill 9 -7/8" hole w/ BHA #3 ( geoPilot) f/ 16525' to 16548' (7519' TVD). Adding dyna red fine and /or nut plug fine 2 sx /10 min (12 sx per hour). Circulate 3 bottom's up pumping 630 gpm w/ 3880 psi - -ECD's 12,64 to 12.54 ppg. Backreaming while circulating, setting back a stand every 45 minutes from 16548' to 15982'. Rotating 140 rpm w/ 25 to 26k ft Ibs of torque. Monitor the well at 15982'- static. Continue to backream pulling 20' /min, pumping 550 gpm w/ 3040 psi. Rotating 100 rpm w/ 25k ft Ibs of torque. Hole packed off while pulling at 15390', run in the hole to 15710', establish circulation (126 gpm w/ 580 psi), increase pump rate to 420 gpm w/ 1900 psi- ECD's 12.56 ppg, then continue to backream f/ 15710' to 14770'. While backreaming f/ 14770' to 14034' increased flow rate to 550 gpm w/ 3050 psi - -ECD's 12.5 to 12.6 ppg. Page 23 of 58 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 16,525 16,548 INTRM1 DRILL DDRL P Continue to directional drill 9 -7/8" hole w/ BHA #3 (geoPilot) f/ 16525' to 16548' (7519' TVD). Actual drilling time .89 hrs. ECD's 12.64 ppg. Drilled w/ 15 to 20k weight on bit, rotating 140 rpm, torque on bottom 25.5k ft Ibs, torque off bottom 23.5k ft Ibs. Pumping 620 gpm w/ 3900 psi. Adding dyna red fine and /or nut plug fine 2 sx/10 min (12 sx per hour). PU wt 370k, SO wt 150k, Rot wt 220k. Jar # 1621 0029= 140.83 hrs. 01:00 06:30 5.50 16,548 15,982 INTRM1 DRILL CIRC P Circulate 3 bottom's up pumping 630 gpm w/ 3880 psi. ECD's 12.64 to 12.54 ppg. Backream slow, pulling and set back a stand every 45 minutes. Rotate 140 rpm w/ 25 to 26k ft Ibs of torque. 06:30 06:45 0.25 15,982 15,982 INTRMI DRILL OWFF P Monitor well- static. 06:45 08:00 1.25 15,982 15,390 INTRMI DRILL REAM P Continue to backream pulling 20' /min. Pumping 550 gpm w/ 3040 psi. ECD's 12.57 to 12.59 ppg. Rotating 100 rpm w/ 25k ft Ibs of torque. Note: Hole packed off while backreaming @ 15390'. 08:00 08:45 0.75 15,390 15,710 INTRM1 DRILL TRIP P Make top drive connections, run back in the hole from 15390' to 15710'. 08:45 09:00 0.25 15,710 15,710 INTRMI DRILL CIRC P Establish circulation at 126 gpm w/ 580 psi. 09:00 12:00 3.00 15,710 15,710 INTRM1 DRILL CIRC P Circulate staging pumps up from 126 gpm w/580 psi to 420 gpm w/ 1900 psi. ECD's 12.56 ppg. Rotating 100 rpm w/ 22k ft Ibs of torque. Rotating weight 215k. 12:00 00:00 12.00 15,710 14,034 INTRM1 DRILL CIRC P Circulate staging pumps up from 126 gpm w/580 psi to 420 gpm w/ 1900 psi. ECD's 12.56 ppg. Backream f/ 15710' to 14770', rotating 100 rpm w/ 22k ft Ibs of torque. Initial rotating weight 215k, final 205k, w/ pump rate of 420 gpm w/ 1900 psi- ECD's 12.56 ppg. Continue to backream f/ 14770' to 14034'. with increased flow rate of 550 gpm w/ 3050 psi, ECD's 12.5 to 12.6 ppg. Page 24 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/03/2009 24 hr Summary Monitor well- static. Trip in the hole on elevators from 14034' to 16454'. Work through some tight hole: 5 to 10k extra weight @ 14704' and 14755', 20 to 25k extra weight @ 14776' to 14806', 14946', 14955' and 14985'. Wash and ream from 16454' to 16528'. 20' of fill on bottom. Rotate 120 rpm w/ 26k ft Ibs of torque. Pumping 495 gpm w/ 2800 psi - -ECD's of 12.73 ppg Circulate and condition mud. Rotating 120 rpm w/ 26k ft Ibs of torque. Reciprocate f/ 16548' to 16454'. Pumping 495 gpm for the first bottom's up w/ 2800 psi - -ECD's of 12.73 to 12.66 ppg. Backream from 16454' to 16268', pumping 610 gpm w/ 3900 psi -ECD's 12.67 to 12.61 ppg. After pumping 3 bottom's up, monitor the well- static. Backream out of the hole from 16268' to 14687'. Pumping 610 gpm w/ 3700 psi- ECD's 12.53. Rotate 120 rpm w/ 25.5k ft Ibs of torque. Continue to backream out of the hole from 14687' to 14500'. Pumping 610 gpm w/ 3700 psi- ECD's 12.48. Rotate 120 rpm w/ 25.5 to 23k ft Ibs of torque. Monitor well- static. Trip in the hole from 14500' to 15963'. Ream through tight spot f/ 15963' to 15987'. Continue to trip in the hole to 16548'. Circulate and condition mud and hole. Pumping 608 gpm w/ 3880 psi- ECD's 12.56 ppg. Backreaming while circulating f/ 16548' to 16355'. Backream out of the hole f/ 16355 to 14490', pulling 9' /minute. Pumping 610 gpm w/ 3620 psi - -ECD's 12.56 ppg. Rotate 120 rpm w/ 25.5k ft Ibs of torque. Rot wt 205k. 00:00 00:15 0.25 14,034 14,034 INTRM1 DRILL OWFF P Monitor well- static. 00:15 03:15 3.00 14,034 16,454 INTRM1 DRILL TRIP P Trip in the hole on elevators from 14034' to 16454'. Work through some tight hole: 5 to 10k extra weight @ 14704' and 14755', 20 to 25k extra weight @ 14776' to 14806', 14946', 14955' and 14985'. 03:15 03:30 0.25 16,454 16,548 INTRM1 DRILL REAM P Wash and ream from 16454' to 16528'. 20' of fill on bottom. Rotate 120 rpm w/ 26k ft Ibs of torque. Pumping 495 gpm w/ 2800 psi. ECD's of 12.73 ppg 03:30 05:15 1.75 16,548 16,454 INTRMI DRILL CIRC P Circulate and condition mud. Rotating 120 rpm w/ 26k ft Ibs of torque. Reciprocate f/ 16548' to 16454'. Pumping 495 gpm for the first bottom's up w/ 2800 psi. ECD's of 12.73 to 12.66 ppg. 05:15 08:15 3.00 16,454 16,268 INTRM1 DRILL CIRC P Backream from 16454' to 16268', pumping 610 gpm w/ 3900 psi. ECD's 12.67 to 12.61 ppg. 08:15 08:30 0.25 16,268 16,268 INTRM1 DRILL OWFF P After pumping 3 bottom's up, monitor the well- static. 08:30 13:30 5.00 16,268 14,687 INTRM1 DRILL REAM P Backream out of the hole from 16268' to 14687'. Pumping 610 gpm w/ 3700 psi, ECD's 12.53. Rotate 120 rpm w/ 25.5k ft Ibs of torque. 13:30 14:30 1.00 14,687 14,500 INTRM1 DRILL REAM P Continue to backream out of the hole from 14687 to 14500'. Pumping 610 gpm w/ 3700 psi, ECD's 12.48. Rotate 120 rpm w/ 25.5 to 23k ft Ibs of torque. 14:30 14:45 0.25 14,500 14,500 INTRMI DRILL OWFF P Monitor well- static. 14:45 15:45 1.00 14,500 15,963 INTRMI DRILL TRIP T Trip in the hole from 14500' to 15963'. Tight spots taking weight @ 15200', 15230', 15830' and 15900'. 15:45 16:00 0.25 15,963 15,987 INTRMI DRILL REAM T Ream through tight spot f/ 15963' to 15987'. 16:00 16:30 0.50 15,987 16,548 INTRMI DRILL TRIP T Continue to trip in the hole from 15987' to 16548'. Page 25 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:00 1.50 16,548 16,355 INTRMI DRILL CIRC T Circulate and condition mud and hole. Pumping 608 gpm w/ 3880 psi. ECD's 12.56 ppg. Backreaming f/ 16548' to 16355'. 18:00 00:00 6.00 16,355 14,490 INTRM1 DRILL REAM T Backream out of the hole f/ 16355 to 14490'. Pumping 610 gpm w/ 3620 psi. ECD's 12.56 ppg. Rotate 120 rpm w/ 25.5k ft Ibs of torque. Rot wt 205k. 11/04/2009 Circulate after backreaming to 14490', Monitor well- static, Trip in the hole on elevators f/ 14490' to 16454'. Tight spots taking weight (30k or more) (a) 15235', 15250', 15432', 15493', 15535', 16145'- 16153', and 163434'. Worked through all tight spots, precautionary ream last 30' from 16518' to 16548', Circulate and condition mud, Load drill string w/ 200 bbls of casing running pill, spot 10 bbls out of the bit, Trip out from 16548' to 14221'. Pulling 20' /min, pumping 2 -3 bpm (90 strokes per stand) w/ 380 to 560 psi, spotting casing running pill beneath the bit in the open hole. Note: Casing running pill consists of: 203 bbls of 11.8 ppg mud w/ 6 ppb soltex, 4 ppb Resinex, 11 ppb Sack Black, 10 ppb safe carb 20, 10 ppb safe carb 40, 5 ppb Alpine beads, 5 ppb G -seal, 2% low torq lube. Backream out of the hole from 14221' to 9994'. Pumping 500 to 588 gpm w/ 2560 to 2900 psi, ECD's 12.45 to 12.63 ppg. Rotate 120 rpm w/ 22.5 to 19k ft Ibs of torque. Pulling speed 10' /minute. 00:00 00:15 0.25 14,490 14,490 INTRMI DRILL CIRC T Circulate after backreaming to 14490', pumping 610 gpm w/ 3620 psi. ECD's 12.56 ppg. Rotate 120 rpm w/ 25.5k ft Ibs of torque. Rot wt 205k. 00:15 00:30 0.25 14,490 14,490 INTRM1 DRILL OWFF T Monitor well- static. 00:30 02:15 1.75 14,490 16,454 INTRMI DRILL TRIP T Trip in the hole on elevators f/ 14490' to 16454'. Tight spots taking weight (30k or more) @ 15235', 15250', 15432', 15493', 15535', 16145'- 16153', and 163434'. Worked through all tight spots. 02:15 02:30 0.25 16,454 16,548 INTRM1 DRILL REAM T Make a top drive connection @ 16454', fill pipe, precautionary ream last 30' from 16518' to 16548'. Pumping 504 gpm w/ 2600 psi. ECD's 12.61 ppg. 02:30 05:45 3.25 16,548 16,272 INTRM1 DRILL CIRC T Circulate and condition mud. Pumping two bottom's up. Backreaming f/ 16548' to 16272' while circulating. Pumping 610 gpm w/ 3880 to 3770 psi. ECD's 12.55 ppg. Rotating 120 rpm w/ 26.5 ft Ibs of torque. 05:45 06:00 0.25 16,272 16,548 INTRM1 DRILL TRIP T Trip in the hole w/ 3 stands on elevators from 16272' to 16548'. 06:00 07:00 1.00 16,548 16,548 INTRM1 DRILL CIRC T Circulate pumping 610 gpm w/ 3780 psi. Load drill string w/ 200 bbls of casing running pill, spot 10 bbls out of the bit. Page 26 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code , ` Subcode T Comment 07:00 10:15 3.25 16,548 14,221 INTRM1 DRILL TRIP T Trip out from 16548' to 14221'. Pulling 20' /min, pumping 2 -3 bpm (90 strokes per stand) w/ 380 to 560 psi, spotting casing running pill beneath the bit in the open hole. Note: Casing running pill consists of: 203 bbls of 11.8 ppg mud w/ 6 ppb soltex, 4 ppb Resinex, 11 ppb Sack Black, 10 ppb safe carb 20, 10 ppb safe carb 40, 5 ppb Alpine beads, 5 ppb G -seal, 2% low torq lube. 10:15 12:00 1.75 14,221 13,940 INTRMI DRILL REAM T Backream out of the hole from 14221' to 13940'. Pumping 500 gpm w/ 2560 psi, ECD's 12.45 to 12.4 ppg. Rotate 120 rpm w/ 22.5k ft lbs of torque. 12:00 18:00 6.00 13,940 11,611 INTRM1 DRILL REAM P Continue to backream out of the hole from 13940' to 11611'. Pumping 500 to 585 gpm w/ 2560 to 3150 psi, ECD's 12.4 to 12.63 ppg. Rotate 140 rpm w/ 22.5 to 20k ft lbs of torque. Pulling speed 10' /minute. 18:00 00:00 6.00 11,611 9,994 INTRM1 DRILL REAM P Continue to backream out of the hole from 11611' to 9994'. Pumping 500 to 588 gpm w/ 3150 to 2900 psi, ECD's 12.63 to 12.5 ppg. Rotate 125 rpm w/ 18 to 20k ft Ibs of torque. Pulling speed 10' /minute. At 9994': PU wt 245k, SO wt 140k, Rot wt 205k, Rot troque 18 to 20k ft Ibs. 11/05/2009 Backream out of the hole from 9994' to 7250'. Pumping 588 to 670 gpm w/ 2900 to 3200 psi, ECD's 12.55 to 12.41 ppg. Rotate 120 to 140 rpm w/ 22 to 16k ft Ibs of torque. Pulling speed 10' /minute to 15' /minute. Hole packing off @ 7150'. ECD's spiked to 13.4 ppg. Circulate and clean up hole while circulating @ 1331'. Pump two LCM pills, one 16 ppb and one 30 ppb (Nut plug fine and dyna red medium). Circulate bringing rate up to 465 gpm w/ 1800 psi. Continue to backream from 7331' to 6855' at midnight to clean the hole. 00:00 06:00 6.00 9,994 7,806 INTRM1 DRILL REAM P Continue to backream out of the hole from 9994' to 7806'. Pumping 588 to 670 gpm w/ 2900 to 3200 psi, ECD's 12.55 to 12.41 ppg. Rotate 120 to 140 rpm w/ 22 to 16k ft lbs of torque. Pulling speed 10' /minute to 15' /minute. Note: ECD's increased f/ 12.4 to 12.7 while reaming stand 63 (7901' to 7806'). Circulated a bottom's up & reduced ECD's to 12.39 ppg. 06:00 08:00 2.00 7,806 7,250 INTRM1 DRILL REAM P Continue to backream out of the hole from 7806' to 7250'. Pumping 575 to 670 gpm w/ 2850 to 3200 psi, ECD's 12.41 to 12.25 to 12.66 ppg. Rotate 120 rpm w/ 16k ft lbs of torque. Pulling speed 107minute to 15' /minute. 08:00 08:15 0.25 7,250 7,250 INTRMI DRILL REAM P Hole packing off while backreaming @ 7250'. ECD's spiked to 13.4 ppg Page 27 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 08:15 12:00 3.75 7,250 7,331 INTRM1 DRILL CIRC P Circulate and condition mud while cleaning up hole at 7331'. Pump 15 ppb LCM pill (Nut plug med, Nut plug fine, Dyna red med 5 ppb each) and 30 ppb LCM pills ( Nut plug med, Nut plug fine, Dyna Red med, 10 ppb each) f/ losses. Pumping 252 to 420 gpm w/ 660 to 1500 psi. ECD's 12.26 up to 12.58 ppg. 12:00 15:45 3.75 7,331 7,236 INTRM1 DRILL CIRC P Circulate to clean hole stand # 57 in the hole.. Pumping 420 to 465 gpm w/ 1500 to 1800 psi. ECD's 12.27 up to 12.51 ppg. 15:45 00:00 8.25 7,236 6,855 INTRMI DRILL REAM P Continue to backream out of the hole from 7236' to 6855'. Pumping 465 to 588 gpm w/ 1750 to 2620 psi, ECD's 12.25 to 12.9 ppg. Rotate 70 -100 rpm w/ 11 to 18k ft Ibs of torque. Pulling speed 2 -3' /minute. Note: Lost 195 bbls of mud to the hole today. 11/06/2009 Continue to BROOh w/ 6,855' - 6,630' MD - Hole packed Off A 6,630' MD RIH 1 Stand Est. Circ and Pump 35 Bbl LCM Sweep - Continue to BROOH t/ 5145' MD Working Though Tight Spots @ 6,345' and 6,240' MD - POOH w/ Pumps t/ 3,335' MD - Circ & Condition Mud at Surface Casing Shoe Working Pump Rate Up f/ 3 to 10 BPM - Slip & Cut Drill Line - OWFF (Flowing) - CBU - OWFF (Static) - POOH w/ Pumps t/ 2,674' MD 00:00 02:30 2.50 6,855 6,630 INTRMI DRILL REAM P Continue to backream out of the hole from 6855' to 6630'. Pumping 588 to 630 gpm w/ 2600 to 2850 psi, ECD's 12.25 to 12.9 ppg. Rotate 70 -100 rpm w/ 11 to 18k ft Ibs of torque. Pulling speed 2 -3' /minute. Note: Lost 195 bbls of mud to the hole today. 02:30 03:00 0.50 6,630 6,630 INTRM1 DRILL CIRC P While backreaming @ 6630', ECD's climbed to 13.14 ppg, hole was packing off. Pumped 35 bbls to the formation while lowering pump rate to 400 gpm trying to reduce ECD's. 03:00 03:15 0.25 6,630 6,761 INTRM1 DRILL TRIP P Run stand # 51 back in the hole to 6761'. PU wt 275k, SO wt 125k, Rot wt 150k. Mix a 35 bbl pill 03:15 05:30 2.25 6,761 6,665 INTRM1 DRILL CIRC P Mix and pump 35 bbl LCM pill @ 336 gpm w/ 725 psi, once to the bit, increase rate to 462 gpm w/ 1700 psi. Circulate LCM pill to surface while backreaming stand # 51. 05:30 12:00 6.50 6,665 5,143 INTRM1 DRILL REAM P Continue to backream f/ 6665' to 5143', Pumping 462 gpm w/ 1690 psi. Rotate 80 rpm w/ 10k ft Ibs of torque. Watching ECD's to keep below 12.3 ppg. - Work Through Tight Spots @ 6345' & 6240' MD 12:00 15:45 3.75 5,143 3,335 INTRM1 DRILL TRIP P POOH w/ Pumps f/ 5143' - 3335' MD - 3 PBM @ 265 Psi 15:45 16:00 0.25 3,335 3,335 INTRMI DRILL OWFF P OWFF - Slight Flow Page 28of58 • • Time Logs Date From To Dur S. Depth E. Depth Phase , Code Subcode T Comment 16:00 19:15 3.25 3,335 3,335 INTRMI DRILL CIRC P Circ & Cond Mud - Staging Pumps Up f/ 3 to 10 BPM @ 1100 Psi w/ 80 RPM - Pumped Nut Plug Sweep w/ No Noticable Increase in Returns When Sweep Returned to Surface 19:15 20:00 0.75 3,335 3,335 INTRM1 RIGMNTSLPC P Slip & Cut Drill Line While Circulating @ 3 BPM 160 Psi 20:00 20:15 0.25 3,335 3,335 INTRMI DRILL OWFF P OWFF - Slight Flow 20:15 21:00 0.75 3,335 3,335 INTRMI DRILL CIRC P CBU, 10 BPM @ 1160 Psi 21:00 21:45 0.75 3,335 3,335 INTRMI DRILL OWFF P Blow Down Top Drive and OWFF - Well initially Flowing @ 20 BPH but Decreased Until Static in 30 Minutes 21:45 00:00 2.25 3,335 2,674 INTRMI DRILL TRIP P POOH w/ Pumps @ 3 BPM f/ 3335' - 2674' MD 11/07/2009 Continue to POOH w/ Pumps - L/D BHA #3 - R/U and Test BOPE t/ 250/3500 Psi - Change Upper Rams t/ 7 5/8" & Test t/ 250/3500 Psi : R/U and Run 7 5/8" Casing per Detail t/ 1,509' MD AOGCC inspector Lou Grimaldi Waived Witnessing the Test 00:00 04:00 4.00 2,674 768 INTRM1 DRILL TRIP P Continue to POOH w/ Pumps @ 3 BPM /180 Psi t/ 786' MD - OWFF (Static) - UD Upper Ghost Reamer (1/2" Under Gauge) 04:00 05:45 1.75 768 195 INTRMI DRILL TRIP P Stand Back 5 Stands of HWDP and UD 2 Jts of HWDP, Jars and Gohst Reamer (3/8" Under Gauge) 05:45 10:30 4.75 195 0 INTRM1 DRILL PULD P UD NMFDC's - Remove nuclear Sources -Read MWD Data - UD Remainder of BHA - Clear Rig Floor 10:30 11:15 0.75 0 0 INTRMI WHDBO PULD P Remove Drilling Wear Ring - Took 25K Pull to Free f/ the Well Head 11:15 12:00 0.75 0 0 INTRM1 WHDBO BOPE P R/U to Test BOPE 12:00 15:00 3.00 0 0 INTRM1 WHDBO BOPE P Test BOPE as Follows: Test Annular Preventer t/ 250/2500 Psi; Test 4" Demco, Choke Manifold Valves 1 -16, Auto /Man IBOP, HCR Choke & Kill Valves, Manual Choke & Kill Valves, Dart, FOSV, Top and Bottom Variable Rams and Blind Rams t/ 250/3500 psi - Perform Accumulator Test - AOGCC Inspector Lou Grimaldi Waived Witnessing the Test 15:00 16:30 1.50 0 0 INTRM1 WHDBO BOPE P Change Upper Rams to 7 5/8" 16:30 17:30 1.00 0 0 INTRMI WHDBO BOPE P Test 7 5/8" Rams t/ 250/3500 Psi 17:30 18:00 0.50 0 0 INTRMI WHDBO PULD P Set Casing Running Wear Ring and R/D Test Equipment 18:00 19:30 1.50 0 0 INTRM1 CASING RURD P R/U to Run 7 5/8" Casing 19:30 20:00 0.50 0 0 INTRM1 CASING SFTY P PJSM w/ Crew & Service Hands on Running 7 5/8' Casing Page 29 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 0 1,509 INTRM1 CASING RNCS P Run 7 5/8" Casing t/ 1,509' MD as Follows: Float Shoe, 2 Jts Casing, HES Float Collar w/ Bypass Baffle Placed on Top, 1 Jt Casing, HES Baffle Collar, 32 Jts Casing - 1 Rigid Blade & 31 Bow Spring Centralizers Placed on First 30 Jts per Detail 11/08/2009 Circ & Condition Mud @ 1,509' MD - RIH w/ Casing t/ 3,350' MD - Circ & Condition Mud - RIH w/ Casing t/ 4,951' MD - Circ & Condition Mud, Lost Returns Staged Pumps Up f/ 1.5 - 3 BPM Regained Returns - RIH w/ Casing t/ 5,505' MD - Circ & Condition Mud - RIH U 6,451' MD - Circ & Condition, Complete 275 Bbl Whole Mud Dilution - RIH t/ 7,091' MD 00:00 01:00 1.00 1,509 1,509 INTRMI CASING CIRC P Circ &Cond Mud @ 1,509' MD Staging Pumps Up f/ 3 to 5 BPM @ 90 - 150 Psi 01:00 04:00 3.00 1,509 3,350 INTRMI CASING RNCS P RIH w/ 43 Jts of Casing t/ 3,350' MD 04:00 05:15 1.25 3,350 3,350 INTRM1 CASING CIRC P Circ & Cond Mud @ 3,350' MD Staging Pumps Up f/ 2 to 5 BPM 05:15 07:30 2.25 3,350 4,951 INTRMI CASING RNCS P RIH w/ 37 Jts of Casing in Open Hole t/ 4,951' MD P/U 160, S/O 125 07:30 12:45 5.25 4,951 4,951 INTRM1 CASING CIRC P Circ & Cond Mud @ 4,951' MD - Staged Pumps Up f/ 1.5 to 3 BPM, Lost Returns, Lowered Pump Rate to 1 BPM @ 120 Psi Unitl Returns Returned then Stage Pumps Up f/ 1 to 4.5 BPM with Full Returns - Lost 130 Bbls 12:45 14:30 1.75 4,951 5,505 INTRM1 CASING RNCS P RIH w/ 13 Jts of Casing w/ Pumps t/ 5,505' MD - Noticed Deminished Returns - 3 BPM @ 200 Psi 14:30 16:00 1.50 5,505 5,505 INTRM1 CASING CIRC P CBU - 3 BPM @ 200 Psi 16:00 18:45 2.75 5,505 6,451 INTRM1 CASING RNCS P RIH w/ 22 Jts of Casing while Puming 3 BPM @ 190 Psi t/ 6,451' MD 18:45 21:30 2.75 6,451 6,451 INTRM1 CASING CIRC P CBU X 3 - Stage Pumps Up f/ 2 to 4.5 BPM - Complete 275 Bbl Whole Mud Dilution w/ Black Product Added to Reduce YP 21:30 00:00 2.50 6,451 7,091 INTRM1 CASING RNCS P RIH w/ 16 Jts Casing While Pumping 3 BPM @ 200 Psi t/ 7,091' MD P/U 210, S/0 137 11/09/2009 Continue to RIH w/ Casing While Pumping U 7,520' MD, Had to Work Through Tight Spot at 7,100' MD - CBU X3, Hole Unloaded - RIH w/ Casing While Pumping t/ 8,573' MD - Circ & Condition Mud - RIH w/o Pumping w/ Casing t/ 9,473' MD - Circ & Condition Mud - RIH w/ Casing t/ 9,687' MD, Pipe Differentially Stuck - Worked Pipe Free / Circulated and Conditioned Mud - Spot 50 PPB LCM Pill f/ 9,187' - 8,273' MD - RIH t/ 10,026' MD, Pipe Stuckbut of Slips - Worked Free / Circulated & Conditioned Mud - RIH t/ 11,573' MD 00:00 01:15 1.25 7,091 7,520 INTRM1 CASING RNCS P Continue to RIH w/ Casing t/ 7,520' MD While Pumping 3 BPM @ 230 Psi - Had to Work Through Hard Spot at 7,100' MD, Set 30K Down and Circulated Several Times Prior to "Breaking Through" P/U 217, S/O 140 Page 30 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ` Comment 01:15 04:30 3.25 7,520 7,520 INTRM1 CASING CIRC P CBU X3 Staging Pumps Up f/ 3 to 4.5 BPM - Hole Unloaded Cuttings Throughout the Second and Third Circulations, Mostly Sand /Silt w/ Trace Amounts of LCM 04:30 08:15 3.75 7,520 8,573 INTRM1 CASING RNCS P Continue to RIH w/ Casing t/ 8,573' MD While Pumping 3 BPM @ 250 Psi P/U 235, S/O 145 08:15 10:30 2.25 8,573 8,573 INTRM1 CASING CIRC P Circ & Cond Mud Staging Pumps Up f/ 2.5 to 4.5 BPM 230 to 290 Psi 10:30 12:00 1.50 8,573 8,960 INTRMI CASING RNCS P Continue to RIH w/ Casing t/ 8,960' MD w/ Pumps @ 3 BPM & 250 Psi 12:00 13:45 1.75 8,960 8,960 INTRMI CASING CIRC P Circ & Cond Mud @ 3 BPM w/250 Psi - Took 175 to Break Over Before Circulation 13:45 15:00 1.25 8,960 9,431 INTRM1 CASING RNCS P RIH w/ Casing (W /O Pumping) t/ 9,431' MD 15:00 15:30 0.50 9,431 9,431 INTRM1 CASING CIRC P Circ 90 Bbls @ 3 BPM w/ 280 Psi 15:30 16:15 0.75 9,431 9,687 INTRMI CASING RNCS P RIH w/ Casing t/ 9,687' MD. Tongs broke and had to be repaired. BO the Jt and pipe sat still a for 10 minutes while repairing tongs. Made up next jt and could not move. Pipe Stuck - Circ 30 minutes. Pull 105 Over to Free Pipe. 16:15 20:15 4.00 9,687 9,687 INTRM1 CASING CIRC P Circ & Cond Mud While Working Pipe - Build 50 PPB LCM Pill of 20 PPB Nut Plug 5, 20 PPB Dyna Red Medium and 10 PPB Sack Black - Spot Tail of LCM Pill in Annulus f/ 9,187' - 8,273' MD. Spot a Lube pill also. 20:15 21:00 0.75 9,687 10,026 INTRMI CASING RNCS P RIH w/ Casing t/ 10,026' MD - Pipe Stuck Coming Out of Slips - Work String to 150 Over Pull, Circ Pumps Up to 5.5 BPM, Shut Pumps Down Pipe Free 21:00 21:45 0.75 10,026 10,026 INTRMI CASING CIRC P Circ 240 Bbls @ 5 BPM w/ 300 Psi 21:45 00:00 2.25 10,026 11,573 INTRM1 CASING RNCS P RIH w/ Casing t/ 11,573' MD, P/U 315, S/O 160 11/10/2009 CBU Ca_ Planned Circulation Point 11,573' MD - Lost Returns After Bottoms Up While Waiting for hale to Clean Up - Work to Get Circulation Back by Reducing Pumps t/ 1/2 BPM and Working Pipe While raising Rate t/ 3 BPM - RIH w/ Casing t/ 12,847' MD - CBU @ Planned Circulation Point - Had Partial Loss of Returns Reduced Pump Rate and Continued to Circ - Attempt to Make Connection (cil 12,847' MD Tried to Move Pipe but Differentially Stuck Pulled up to 200K Over and Re- Established Circulation - Pipe Still Stuck @ Midnight Mud Lost to Formation for Previous 24 Hrs - 423 Bbls 00:00 02:30 2.50 11,573 11,573 INTRMI CASING CIRC P CBU Staging Pumps Up f/ 1 to 4 BPM - Hole Unloaded Cuttings (Sand, Clay & LCM) at Bottoms Up Page 31 of 58 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 06:30 4.00 11,573 11,573 INTRMI CASING CIRC T Lost Circulation After Bottoms Up While Pumping 4 BPM @ 300 Psi - Flow Decreased f/ 19 % to 0% on flow indicator. (full returns to partial returns)- Reduced Pump Rate to 1/2 BPM, Then Increased Gradually to 1 1/2 BPM on the Down Stroke and 3 BPM on the Up - Pumped 35 Bbl 50 PPB LCM Pill - Full Returns Regained and Pumps Eased Up f/ 1 1/2 to 3 BPM on the Down Stroke with Full Returns Maintained - Calculated 128 Bbls Pumped Into the Formation 06:30 08:00 1.50 11,573 12,847 INTRMI CASING RNCS P RIH w/ Casing t/ 12,84T MD - P/U 340, S/O 158 08:00 12:00 4.00 12,847 12,847 INTRM1 CASING CIRC P CBU Staging Pumps Up f/ 1 to 3 BPM w/ 290 - 360 Psi - Noted Diminished Returns Flow Out Dropped f/ 19 to 9% at Bottoms Up Mud Lost for Tour 149 Bbls 12:00 18:45 6.75 12,847 12,847 INTRM1 CASING RNCS T M/U 1 Jt of Tubing and Attempt to RIH - Attempt to work Pipe Up and Down Setting Down to Block Weight and Pulling Up to 200 w/ No Affect - Lost Circulation Returns Dropped to 0% on Mud Watch & Only a Slight Stream of Mud Visible Going Down the Flow Line - Closed Rams and Attempt to Circulate 10 Bbls Down Back Side @ 2 BPM 200 Psi - Open Rams and Circulate Conventionally @ 3 BPM w/ 300 Psi - Regained Full Returns - Continue to Work Pipe - Pulled a Maximum Indicated Weight of 550K Measured Pipe Stretch: 150K = 0 ", 200K = 7.5 ", 250K = 22 ", 300K = 38.5 ", 350K = 52 ", 400K = 67" 18:45 00:00 5.25 12,847 12,847 INTRM1 CASING CIRC T Shut Down Pumps and Monitor Flow Back to Confirm Breathing - 26 Bbls Returned in 25 Minutes w/ Rates Decreasing f/ 120 to 60 BPH - Circ and Condition Mud While Lowering Mud Weights .2 to 11.6 PPG - Continue to Work Pipe Pulling Up to 425K w/ Pumps © 3 BPM and 525K w/ Pumps Off and Slacking Off to Block Weight Mud Lost for Tour - 274 Bbls Page 32 of 58 ! • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/11/2009 24 hr Summary Continue to Circulate and Condition Mud Lowering Mud Weight to 11.6 PPG While Working the Casing Pulling Up to 200K Over and Setting Down to Block Weight - R/U and Cement First Staae w/ 60.7 BBIs of 15.9 PPG Class G - Close Pipe Rams Due to Breathing and WOC - Open HES Stage Collar, CBU and Cement 2nd Stage Through Collar w/ 44 Bbls of 15.9 PPG Class G Cement - Close Stage Collar and Pipe Rams - WOC 00:00 04:30 4.50 12,844 12,844 INTRMI CASING CIRC T Circulate & Cond Mud to Lower MW to 11.6 f/ 11.8 PPG - Work Pipe Up & Down Pulling to 550K w/ Pumps Off and 420K w/ Pumps @ 3 BPM the Setting Down to Block Weight - No Effect - Well Breathing w/ Pumps Off 04:30 07:30 3.00 12,844 12,844 INTRM1 CASING CIRC T Circulate 3 bpm / 280 psi with 11.6 ppg mud wt. in & out - Continue working stuck pipe to 420k PUW with pumps on and Staging up to 550K PUW with pumps off - slacking off to block wt. - No Movement 07:30 07:45 0.25 12,844 12,844 INTRM1 CASING SFTY T PJSM - on laying down casing 07:45 08:45 1.00 12,844 12,844 INTRMI CASING PULD T Lay down joint #301 - lay down fill up tool - blow down top drive 08:45 09:30 0.75 12,844 12,844 INTRM1 CEMEN" RURD P Rig up cement head and lines - establish circulation - 3 bpm / 270 psi Page33of58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 13:30 4.00 12,844 12,844 INTRM1 CEMEN CMNT P Line up to cementers - pumped 4 bbls of CW100 - test lines to 4000 psi - continue pumping CW100 20 bbls total - Pumped 47 bbls of 12.5 ppg MudPush @ 4 bpm / 420 psi - shut down bled lines and cement head - load 1st stage top plug in head - pumped out plug with last 5 bbls of Mudpush - 52 bbls total - Pumped 295 sxs G cement w/ adds. (60.7 bbls) @ 4 bpm 447 - 211 psi - dropped top plug - Dowell displaced with 20 bbls of FW - switch to rig pumps and displaced with 11.6 ppg mud @ 4 bpm / 300 - 240 psi for first 485 bbls - increased rate to 5 bpm (25 bbls of MudPush around shoe) 320 - 540 psi - slowed rate to 3.5 bpm @ 400 psi for last 4 bbls pumped (total 562 bbls mud) - bumped plug to 1000 psi - CIP @ 1312 hours - Full returns while cementing - Observed well breathing - shut in well with pipe rams @ 1315 hours to avoid potential contamination of cement. Checked floats, held. Blow down cement lines - Install gauge on casing and monitor _L pressures - SICP 5 psi, SI annulus F pressure 35 psi. emented casing with shoe @ 12,844', FC @ 12,751', Baffle Collar © 12,706', stage Collar @ 5878' and port Colar @ 4902' 13:30 19:30 6.00 12,844 12,844 INTRMI CEMEN" WOC . • - ' ams - W< • ement - Monitor Annular/ Casing Pressures - Initail Annular / Casing Pressure = 25 / 5 Psi - Final Annular / Casing Pressure 30 / 160 Psi 19:30 21:00 1.50 12,844 12,844 INTRMI CEMEN" CIRC P Pressure Up Casing t/ 3650 Psi and Shift Open HES Stage Collar - CBU @ 4 BPM w/ 290 Psi 21:00 22:45 1.75 12,844 12,844 INTRM1 CEMEN" CMNT P Perform 2nd Stage Cement as Follows: Dowell Pumped 20 Bbls CW 100 @ 4 BPM, 22 Bbls of Mud Push @ 4 BPM, 44 Bbls of 15.9 PPG Class G Cement @ 4 BPM, Drop HES "Closing" Plug, Pump 20 bbls Fresh Water - Displace Cement w/ 248 Bbls of Mud - Plug on Seat at 2,480 Strokes - Pressure Up Casing t/ 2380 Psi - Collar Closed & Pressure Held @ 2340 Psi f/ 3 Minutes - CIP @ 2245 hrs - Calculated TOC 4,729' MD - 95% of Volume Pumped During Cement Job Returned (101 of 106 Bbls) Page34of58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 22:45 00:00 1.25 12,844 12,844 INTRMI CEMEN' WOC T Close Pipe Rams - Wait on Cement 11/12/2009 Continue to WOC w/ Rams Closed - Open Well and Allow Annulus to Flow Until Static - Nipple Down BOPE Stack and Tubing Spool - Set Emergency Slips, Cut and Dress Casing Joint and Set Packoff - N/U Tubing Spool and BOPE Stack - Test Packoff and Flange to 5,000 Psi - Slip & Cut Drill Line - UD 5" DP via the Mouse Hole 00:00 02:15 2.25 12,841 12,841 INTRMI CEMEN' WOC T Continue to WOC w/ Pipe Rams Closed - Casing / Annulus Pressure 15/0 Psi 02:15 08:45 6.50 12,841 12,841 INTRMI CEMEN' OPNW T Open Rams and Allow Annulus to Flow Until Static (Exhale) - Rate Continuously Decreasing 08:45 09:15 0.50 12,841 12,841 INTRMI CEMEN' RURD P R/D Cement Head and Equipment 09:15 12:00 2.75 12,841 12,841 INTRM1 WHDBO OTHR T Drain & Flush BOPE Stack - Blow Down Choke & Kill Lines - Set up to Pick Up BOPE Stack for Setting Emergency Slips & Cutting Casing 12:00 13:00 1.00 12,841 12,841 INTRMI WHDBO NUND T Remove Bolts f/ Well Head and P/U Stack 13:00 16:30 3.50 12,841 12,841 INTRM1 CASING CPBO T Center Casing, Pull 225K (75 Over) & Set FMC 7 5/8" Emergency Slips - Slacked Off Weight and Completed Rough Cut of Casing - Pull Cut Joint f/ Stack and Move BOPE Stack Away f/ Work Area - Complete Final Cut/Dress of Casing Joint - Set Packoff 16:30 18:00 1.50 12,841 12,841 INTRMI WHDBO NUND T Set Wellhead and BOPE - Tighten Bolts - Test Packoff & Flange t/ 5,000 Psi f/ 15 Minutes - N/U Riser, Flow Line, & Surface Lines - UD Casing Equipment 18:00 19:15 1.25 0 0 INTRM1 DRILL SLPC P Slip & Cut Drill Line - Service Draw Works & Top Drive 19:15 00:00 4.75 0 0 INTRM1 DRILL PULD P UD 5" DP via Mouse Hole 11/13/2009 UD 5" DP via the Mouse Hole - Change Upper Rams to 3 1/2" X 6" Variables - Test BOPE t/ 250/2500 Psi & 250/3500 Psi w/ 3 1/2 ", 4" & 4 1/2" Test Joints - P/U 10 Stands of 4" DP and Stand Back - P/U Clean Out BHA 00:00 12:00 12.00 0 0 INTRMI DRILL PULD P UD 5" DP via Mouse Hole ( 522 jts. total) - Lay down 18 jts of 5" HWDP 12:00 12:30 0.50 0 0 INTRMI DRILL OTHR P Pull wear bushing from wellhead 12:30 13:30 1.00 0 0 INTRM1 WHDBO OTHR P Change top pipe rams to 3 1/2" x 6" VBR's - change out TD saver sub to 4" XT 13:30 14:00 0.50 0 0 INTRM1 WHDBO RURD P Set test plug - fill stack with water - RU to test BOP's Page 35 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 21:00 7.00 0 0 INTRM1 WHDBO BOPE P Test BOPE as Follows: Bind Rams, Test Choke Manifold Valves 1 -16, IBOP, FOSV, Dart & 4" DEMCO Valve to 250/3500 Psi - Test Annular Preventer w/ 3 1/2 ", 4" & 4 1/2" Test Jts t/ 250/2500 Psi - Test Upper and Lower Variable Rams w/ 3 1/2 ", 4" & 4 1/2" Test Jts t/ 250/3500 Psi - Completed Accumulator Draw Down Test - Test Failures: Valve #3, and Two Pressure Sensors, All Defective Parts Serviced /Replaced and Re- tested Satisfactorily - AOGCC Inspector Jeff Jones Waived Witnessing the Test 21:00 21:30 0.50 0 0 INTRMI WHDBO RURD P Pull Test Plug, Install Wear Ring, R/D BOPE Test Equipment 21:30 00:00 2.50 0 182 INTRM1 DRILL PULD P R/U to P/U 4" DP - 10 Stands of 4" DP and Stand Back - Clean Out BHA t/ 182' MD - Verified Bit and Ghost Reamer OD @ 6 3/4" 11/14/2009 Continue to M/U Clean Out BHA & RIH w/ Singles f/ the Pipe Shed - Wash /Ream Past TAM Port Collar - RIH w/ Singles t/ 5,809' MD - Test Casing t/ 3500 Psi f/ 10 Minutes - Drill Out Stage Collar and Cement Stringers Below - Test Casing t/ 3500 Psi f/ 5 Minutes - RIH w/ Singles f/ the Pipe Shed t/ 12,845' MD - Wash /Ream t/ Top of Baffle Collar © 12,706' MD - CBU - POOH on Elevators t/ 4,955' MD - Wash /Ream Though TAM Port Collar 00:00 00:30 0.50 182 369 INTRMI DRILL PULD P Continue to MU BHA #4 - M/U XO, P/U drilling jars and 5 jts. of 4" hwdp - RIH to369' 00:30 04:45 4.25 369 4,686 INTRM1 DRILL PULD P RIH picking up 4" drill pipe from shed to 4886' - PUW 135K SOW 110K 04:45 05:30 0.75 4,686 4,950 INTRMI DRILL WASH P Est. Circ and Wash /Ream to TAM Port Collar - Tagged at 4,902' MD - Rotated Through TAM PC @ 20-40 RPM While Pumping 3 BPM @ 400 Psi - Set Down 8K and Torque Rose to 8,000 While Stablizer Passed Thorugh Collar - Pressure Tested Casing t/ 1400 Psi After Passing Collar 05:30 06:30 1.00 4,950 5,809 INTRM1 DRILL PULD P RIH picking up 4" drill pipe from shed to 5809' 06:30 07:15 0.75 5,809 5,809 INTRM1 DRILL PRTS P RU and test casing to 3500 psi for 10 minutes - RD & blow down lines 07:15 09:45 2.50 5,809 6,190 INTRMI DRILL OTHR P Wash and ream from 5809' to 5870' - 252 gpm / 1200 psi / 60 - 80 rpm @ 7500 ft/lbs - clean out cement from 5870' to 5878' - Drill out stage collar and cement below to 5900' - Increased rate to 378 gpm / 2100 psi - rpm to 100 @ 8000 ft/Ibs - washed down to stands and slid 3rd stand w/o pup to 6190' - no indication of cement below 5900' obserevd 09:45 10:15 0.50 6,190 5,809 INTRM1 DRILL TRIP P Blow down top drive - stand back 4 stands in derrick Page 36 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase `'Code Subcode T Comment 10:15 10:30 0.25 5,809 5,809 INTRM1 DRILL PRTS P Pressure test casing to 3500 psi for 5 minutes, good 10:30 16:15 5.75 5,809 12,485 INTRMI DRILL PULD P RIH picking up 4" drill pipe from shed to 12485' - fill pipe every 20 stands 16:15 17:30 1.25 12,485 12,485 INTRM1 DRILL PRTS P RU and test casing to 3500 psi for 30 minutes, good - RD & blow down lines 17:30 18:30 1.00 12,485 12,706 INTRMI DRILL WASH P Wash / Ream Casing @ 60 RPM Pumping 6 BPM @ 1790 Psi - Tagged Baffle Collar on Depth @ 12,706' MD Set 30 K Down to Verify Good Whipstock Foundation 18:30 19:45 1.25 12,706 12,706 INTRM1 DRILL CIRC P CBU - 8 BPM @ 1800 Psi, 60 RPM 19:45 23:00 3.25 12,706 4,955 INTRM1 DRILL TRIP P POOH on Elevators t/ 4,955' MD 23:00 00:00 1.00 4,955 4,859 INTRMI DRILL REAM P Ream TAM Port Collar - Initially Took 10K and Torqued Up but Conditions Improved w/ Each Pass 11/15/2009 Continue to Ream TAM port Collar w/ Bit/Stabilizer, On Final Pass noted 2K Drag as Stabilizer Blades Passed Through the Collar - POOH on Elevators to Surface - P/U Whipstock BHA and RIH on 4" DP f/ the Pipe Shed and Derrick t/ 6,665' MD - Conducted Casing Pressure Test t/ 2,500 Psi f/ 5 Minutes - Continued to RIH w/ DP f/ the Derrick t/ 12,581' MD - Kelly Up and Orient MWD to 46° Left of High Side - Land & Set Whipstock String w/ Tubing Tail @ 12,706' MD - Shear Mill f/ Whipstock, Take Base Line ECD Readings and Mill Window f/ 12,675' - 12,678' MD Note: Top & Bottom of Ramp = 12,675' / 12,688' MD 00:00 00:45 0.75 4,859 4,859 INTRMI DRILL REAM P Continue to Ream TAM PC - Final Pass Through Noted 2K Drag When Stabilizer Blades were Slid Across w/o Rotation or Pumps - Total Passes Through Collar 15 00:45 03:30 2.75 4,859 0 INTRM1 DRILL TRIP P POOH - Stand Back HWDP and DC's - Noted Large Rubber Piece Lodged in Bit Possibly Possibly from the Baffle Adapter - Removed Rubber 03:30 03:45 0.25 0 0 INTRM1 DRILL SFTY X PJSM on handling Whipstock components 03:45 06:15 2.50 0 89 INTRM1 WHPST PULD X MU Whipstock milling assembly w/ MWD and PWD collars - scribe MWD - upload MWD 06:15 09:30 3.25 89 490 INTRM1 WHPST TRIP X P/U Whipstock - attach milling assembly to ramp with 35K shear bolt - MU Bumper jar - RIH w/ (6) 4 3/4" DC's & 5 joints of 4" hwdp and 1 jt. of drill pipe to 490' - shallow test MWD 09:30 16:00 6.50 490 6,665 INTRM1 WHPST TRIP X RIH picking up 4" drill pipe from shed to 2751' (72 joints) then Continue to Rlh w/ Stands f/ Derrick t/ 6665' MD (41 Stands) 16:00 16:45 0.75 6,665 6,665 INTRMI WHPST PRTS X R/U and Pressure Test Casing t/ 2500 Psi f/ 5 Minutes - Blow Down Lines 16:45 21:45 5.00 6,665 12,581 INTRM1 WHPST TRIP X Continue to RIH w/ DP f/ the Derrick t/ 12,581' MD Page 37 of 58 Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 21:45 22:30 0.75 12,581 12,680 INTRM1 WHPST SRVY X Kelly Up and Orient Whipstock to 46° Left of High Side - Pumping 7 BPM @ 2920 Psi 22:30 00:00 1.50 12,680 12,706 INTRMI WHPST WPST X M/U Stand 129 and Set Whipstock @ 46° Left of High Side as Follows: Tagged Baffle Collar on Depth @ 12,706 MD, Set Down 8K to Set Anchor, Pull 15k Over to Verify Anchor Set, Set Down 42K to Shear Mill to Whipstock Bolt - Bottom & Top of Whipstock Slide @ 12,675 / 12,688' MD - P/U and Take Base Line ECD's w/o Rotating as Follows: MW = 11.4 PPG 5 BPM @ 1600 Psi ECD 12.24 6 BPM @ 2150 Psi ECD 12.35 7 BPM @ 2800 Psi ECD 12.49 8 BPM @ 3480 Psi ECD 12.67 Mill Window f/ 12,675 - 12,678' MD - 6 BPM @ 2180 Psi, 100 RPM @ 16,000 Torque P/U 225, S/O 118, Rot 160 11/16/2009 Continue of Mill Window in 7 5/8" Casing t/ 12,724' MD (TOW 12,675' MD, BOW 12,688' MD) - Work Mills Through Window Several Times w/ and w/o Rotation - Pump "Super Sweep" - OWFF (Static) - POOH on TT t/ 433' MD - UD Milling BHA - Pull Wear Ring, Set Junk Catcher Wear Ring, & Wash Stack - Function Rams 00:00 09:15 9.25 12,706 12,724 INTRMI WHPST WPST X Continue with Window milling operations - f/ 12,678' - 12,724' MD 6075' TVD Top of window @ 12,675' MD Btm. of window @ 12,688' MD P/U 200K, S/O 125K, Rot 155K ADT 9.25 hrs. WOB 6 -10 Torque 16,000 @ 100 RPM 240 GPM @ 2090 Psi 09:15 11:00 1.75 12,724 12,645 INTRM1 WHPST CIRC X Circulated High Vis sweep w/ 0.1 ppb Super Sweep fibers - Worked mills across window several passes - shut down pumps and rotary - slid assembly to bottom, pulled back into casing without problems. Flow check well, static - Stand back one stand to 12,645' - P/U 200K, S/O 125K, Rot 155K Torque 15,500 @ 80 RPM 240 GPM @ 2090 Psi Mud Wt. 11.6ppg In- 11.6ppgout ECD @ 13.1 ppg Page 38 of 58 1 e Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:45 0.75 12,645 12,645 INTRMI WHPST FIT XT RU to perform FIT - Line up to Cementers - establish circulation - Pressure test lines to 1500 psi - had difficulty with pumps getting suction - trouble shoot pumps - unable to get reliable output from pumps - abandon attempt at FIT with cement unit 11:45 12:15 0.50 12,645 12,645 INTRMI WHPST FIT X Line up to rig pumps - Perform FIT to 13.5 ppg EMW - 11.6 ppg mud / 610 psi applied surface pressure - RD - blow down lines 12:15 13:30 1.25 12,645 11,722 PROD1 WHPST TRIP X Flow check well, static - Line up on trip tank - POOH from 12,645 to 11,722' (10 stands) had proper displacement 13:30 13:45 0.25 11,722 11,722 PROD1 WHPST TRIP X Pump dry job - blow down top drive - line up on trip tank 13:45 20:45 7.00 11,722 433 PROD1 WHPST TRIP X Continue to POOH on Elevators t/ 433' MD - Flow Checked Well @ 3,132' MD (Static) 20:45 22:15 1.50 433 0 PROD1 WHPST PULD X Rad MWD Data and UD Milling BHA - Noted Starter Mill 1/4" Under Gauge, All Others In Gauge 22:15 22:45 0.50 0 0 PROD1 DRILL PULD X Clean & Clear Rig Floor 22:45 00:00 1.25 0 0 PROD1 DRILL OTHR X Pull Bowl Protector / Set "Junk Catcher" Bowl Protector - Function Rams - Wash Stack - Install Short Bowl Protector and RILDS 11/17/2009 UD Geo -Span - P/U BHA #6, shallow test MWD @ 375', pick up 12 joints of 4" from pipe shed, PJSM, slip and cut 60' of drilling line, service top drive, continue trip in the hole to 4856', wash and ream past the TAM port collar @ 4902', continue trip in from 4951' to 12587' filling pipe every 20 stands, orient motor to 45 deg left, slide past whipstock (TOW @ 12675', BOW @ 12688') to 12724'. Directional drill from 12724' to 13020' (appeared to enter the old hole @ 12890' by penetration rate), circulate and condition mud while discussing situation w/ town. Wash down from 13020' to 13063', slacking off 1300' /hr. Increasing mud weight from 11.4 ppg to 11.6 ppg. Wash in the hole to 13159' at midnight. 00:00 00:15 0.25 0 0 PROD1 DRILL SFTY X PJSM on P/U BHA 36 and UD the Geo -Span 00:15 00:30 0.25 0 0 PROD1 DRILL PULD X UD the Geo -Span 00:30 03:30 3.00 0 375 PROD1 DRILL PULD X P/U BHA #6 as Follows: Motor, Float Sub, Stabilizer, PCDC, SP4, PWD & TM - M/U 6 3/4" Bit and Upload MWD Data - P/U NMFDC's, Jars & HWDP t/ 375' MD 03:30 03:45 0.25 375 375 PROD1 DRILL DHEQ X Shallow Pulse Test MWD Tools 03:45 04:15 0.50 375 752 PROD1 DRILL TRIP X RIH w/ 12 Singles of 4" DP f/ the Shed t/ 752' MD 04:15 05:45 1.50 752 752 PROD1 DRILL SLPC X PJSM; Slip & Cut 60' of Drill Line, Service Top Drive & Adjust Draw Works Brakes 05:45 07:45 2.00 752 4,856 PROD1 DRILL TRIP X Continue to RIH w/ 4" Dp f/ the Derrick t/ 4856 Page 39 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 08:00 0.25 4,856 4,951 PROD1 DRILL REAM X Wash and ream while passing by the TAM port collar @ 4902'. Ream from 4856' to 4951'.Pumping 126 gpm w/ 800 psi. Rotate 20 rpm w/ 6k ft Ibs of torque. 08:00 13:00 5.00 4,951 12,587 PROD1 DRILL TRIP X Continue to RIH w/ 4" Dp f/ the Derrick t/ 12587'. Fill pipe every 20 stands. 13:00 13:30 0.50 12,587 12,724 PROD1 DRILL REAM X Orient motor to 45 degrees left. Slide thru window (TOW @ 12675', BOW 12688'). Wash /Ream to 122724'. Pumping 253 gpm w/ 2800 psi. 13:30 18:00 4.50 12,724 12,798 PROD1 DRILL DDRL X Directional drill w/ 1.22 deg bend motor from 12724' to 12798'. Weight on bit 3 to 10k. Pumping 287 gpm w/ 3290 psi, Rotate 30 rpm w/ 11k ft Ibs on and 11.5 k ft lbs off bottom. PU wt 195k, SO wt 125k, Rot wt 160k. ART = .7 hrs, AST = 1.04 hrs. Total bit hours 1.74 hrs 18:00 21:15 3.25 12,798 13,020 PROD1 DRILL DDRL X Directional drill w/ 1.22 deg bend motor from 12724' to 13020'. Weight on bit 3 to 10k. Pumping 287 to 277 gpm w/ 3290 to 2600 psi, Rotate 30 to 80 rpm w/ 11 to 13.5k ft Ibs on and 11.5 k ft lbs off bottom. PU wt 200k, SO wt 125k, Rot wt 168k. ART = 1.74 hrs, AST = .55 hrs. Total bit hours 4.03 hrs. Note: Appeared to enter old wellbore @ 12890' (1950 hrs). Penetration rate went from 30 to 55 ' /hr to 250' /hr, control) drilled at 100' /hr after seeing 250' /hr. . 21:15 23:30 2.25 13,020 13,063 PROD1 DRILL CIRC X Circulate and condition mud and hole. Discuss situation with town. Pumping 252 gpm w/ 2500 psi. Rotate 70 rpm w/ 12k ft Ibs of torque. Wash down from 13020' to 13063' without rotary, slacking off 1075'/hr, confirming in old hole. Start increasing mud weight from 11.4 ppg to 11.6 ppg. 23:30 00:00 0.50 13,063 13,159 PROD1 DRILL WASH X Wash from 13063' to 13159' , pumping 220 gpm w/ 2020 psi. After washing down, backream w/ 50 rpm. PU wt 210k, SO wt 125k, Rot wt 170k. Take survey's before connection, appear to be in old hole. slacking off 320' /hr. 11/18/2009 Wash from 13159' to 13349', circulate and weight up from 11.4 ppg to 11.8 ppg, pump out of the hole from 13349' to 12675', monitor well- static, continue pumping out of the hole to 8866',monitor well- slight flow (breathing), attempt to pull with out pumping- swabbing, continue to pump out to 4093', pull out of the hole on elevators to 2570' at midnight, monitoring hole on the trip tank. Page 40 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 13,159 13,349 PROD1 DRILL REAM XT Wash from 13159' to 13349' , pumping 220 gpm w/ 2020 psi. After washing down, backream w/ 50 rpm. PU wt 210k, SO wt 125k, Rot wt 170k. Take survey's before connection, appear to be in old hole. slacking off 1055'/hr. 00:30 05:30 5.00 13,349 13,349 PROD1 DRILL CIRC XT Circulate and condition mud and hole, increasing mud weight from 11.4 ppg to 11.8 ppg. Pumping 220 gpm w/ 2020 psi. Rotate 50 rpm w/ 12k ft Ibs of torque. 05:30 06:45 1.25 13,349 12,675 PROD1 DRILL TRIP XT Pump out of the hole. Pumping 220 gpm w/ 2150 psi. PU wt 235k, Slack off wt 125k 06:45 07:00 0.25 12,675 12,675 PROD1 DRILL OWFF XT Monitor well- static 07:00 13:30 6.50 12,675 8,866 PROD1 DRILL TRIP XT Pump out of the hole. Pumping 126 gpm w/ 980 to 900 psi. PU wt 180k, Slack off wt 115k 13:30 13:45 0.25 8,866 8,866 PROD1 DRILL OTHR XT Blow down the top drive. 13:45 14:45 1.00 8,866 8,866 PROD1 DRILL OWFF XT Monitor well- slight flow ( Breathing), initial 3.67 bph, static after 50 minutes. 14:45 15:00 0.25 8,866 8,866 PROD1 DRILL TRIP XT Attempt to pull without pumping - swabbing. 15:00 21:30 6.50 8,866 4,093 PROD1 DRILL TRIP XT Pump out of the hole. Pumping 126 gpm w/ 800 psi. 21:30 00:00 2.50 4,093 2,570 PROD1 DRILL TRIP XT Pull out of the hole on elevators, monitor well on the trip tank. 11/19/2009 Continue to pull out of the hole on elevators f/ 2570' to the BHA @ 375', monitoring hole on the trip tank, monitor well- static, continue to pull out with the BHA to 95' (calculated displacement f/ trip was 83.6 bbls, actual 110.5 bbls), PJSM, break off bit, download MWD, lay down BHA, PJSM, rig up to run 3 -1/2" tubing stinger, PJSM, pick up/ make up mule shoe plus 30 joints of 3 -1/2" EUE 9.3 ppf L -80 tubing (943'), rig down tubing running tools, rig up 4" elevators, run in the hole w/ 3 -1/2" stinger on 4" drill pipe to 13347', Circulate and condition mud, lay in a hi vis pill from 13337' to 13186', condition mud, Cement per Dowell program, pull out of the hole, stripping through the bag to keep cement in place from 13286' to 12393', circulate bottom's up, monitor well- slight flow , stand back a stand, shut in well to monitor pressure on dp and annulus. Zero pressure at midnight. 00:00 01:45 1.75 2,570 375 PROD1 DRILL TRIP XT Continue to pull out of the hole on elevators, monitor well on the trip tank. 01:45 02:00 0.25 375 375 PROD1 DRILL OWFF XT Monitor well at the HWDP- static. 02:00 02:30 0.50 375 95 PROD1 DRILL TRIP XT Continue to pull out of the hole on elevators, monitor well on the trip tank. Note: Calculated displacement f/ trip 83.6 bbls, actual 110.5 bbls. 02:30 02:45 0.25 95 95 PROD1 DRILL SFTY XT Pre job safety meeting on BHA. 02:45 03:30 0.75 95 30 PROD1 DRILL PULD XT Break off bit, download Sperry Sun MWD. 03:30 04:00 0.50 30 0 PROD1 DRILL PULD XT Lay down BHA. 04:00 04:15 0.25 0 0 PROD1 DRILL SFTY XT Pre job safety meeting on rigging up to run 3 -1/2" tubing to cement through. Page 41 of 58 4110 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:30 0.25 0 0 PROD1 DRILL RURD XT Rig up to run 3/12" tubing. 04:30 04:45 0.25 0 0 PROD1 DRILL SFTY XT Pre job safety meeting on running 3 -1/2" tubing to cement through. 04:45 06:00 1.25 0 943 PROD1 DRILL PULD XT Pick up/ Make up 30 joints of 3 -1/2" EUE tubing, 9.3 ppf L -80. Torque to 2300 ft Ibs, drift to 2 -3/8 ". 06:00 06:15 0.25 943 943 PROD1 DRILL RURD XT Rig down tubing running tools, rig up to run 4" drill pipe. 06:15 11:30 5.25 943 13,377 PROD1 DRILL TRIP XT RIH with 4" drill pipe from 943' to 13,377' 11:30 13:30 2.00 13,377 13,377 PROD1 CEMEN "CIRC XT Establish circulation - stage pumps up to 5.O bpm / 1220 psi - reciprocate pipe - condition mud - PUW 212K SOW 120K 13:30 14:15 0.75 13,377 13,186 PROD1 CEMEN"CIRC XT Pump 32 bbls of high vis gel pill - displace to bottom - POOH to 13,186' spotting pill into open hole 3.2 bpm / 740 psi - 1400 fph 14:15 16:00 1.75 13,186 13,186 PROD1 CEMEN" CIRC XT Circulate and condition mud 5 bpm / 1240 psi until 11.8ppg in & out - no losses observed PUW 220K SOW 125 -130K - PJSM - discussed stripping operations if needed 16:00 17:15 1.25 13,186 13,186 PROD1 CEMEN"CMNT XT With tbg. tail @ 13,186' - Line up to cementers - establish circulation with 4 bbls of 12.5 ppg MudPush - Test lines to 2500 psi - pump additional 8 bbls of mudPush - Mixed and pumped 285 sxs G cmt. (51.5 bbls) 17.0 ppg lcf/sx yld. - displaced to equalization with 4 bbls of 12.5 ppg mudPush and 117.5 bbls of 11.8 ppg mud - Reciprocated pipe - PUW 220K SOW 125K - had full returns throughout - CIP @ 1703 hrs. - RD cement line and head pin. 17:15 18:15 1.00 13,186 12,393 PROD1 CEMEN "TRIP XT Began POOH - observed well swabbing - Closed annular preventor - Stripped out 8 stands of drill pipe from 13,186' to 12,393' - opened annular - observe well, static 18:15 20:30 2.25 12,393 12,393 PROD1 CEMEN "CIRC XT Circulate bottom's up, pumping 168 gpm w/ 950 psi. 20:30 20:45 0.25 12,393 12,393 PROD1 CEMEN" OWFF XT Monitor well- slight flow. 20:45 21:00 0.25 12,393 12,297 PROD1 CEMEN "TRIP XT Stand back a stand, while pumping out. 21:00 00:00 3.00 12,297 12,297 PROD1 CEMEN SIPB XT Shut in well to observe pressure on drill pipe and annulus. Final pressure was zero on the drill pipe and annulus. Page 42 of 58 Time Logs Date From To : Dur S. Depth E. Depth Phase Code Subcode T Comment 11/20/2009 24 hr Summary Trip in the hole to tag top of cement: run 12297 to 12393', wash in- pumping 84 gpm f/ 12393' to 12650' (25' above TOW) (No indication of cement), circulate bottom's up (Cement contaminated mud @ BU), wash in f/ 12650' to tag top of cement @ 12813' w/ 7k weight. Circulate and condition mud pumping 210 gpm w/1250 psi. PJSM, RU to pump Kick off plug #2, perform cement job w/ Dowell, POOH f/ 12813' to 12575', circulate /condition /treat contaminated mud, wash in f/ 12575' to tag top of cement @ 12604' w/ 5k wt and 120 psi pump increase, stand back a stand, blow down the top drive, monitor well- static, pull out of the hole w/ 3 -1/2" cement stinger and 4" drill pipe f/ 12583' to 6857' @ midnight. 00:00 00:15 0.25 12,297 12,393 PROD1 CEMEN" TRIP XT Trip in the hole to tag the top of cement. Trip in f/12297 to 12393'. PU wt 220k, SO wt 121k. 00:15 01:15 1.00 12,393 12,650 PROD1 CEMEN" WASH XT Wash in the hole to within 25' of the top of the window. Washed from 12393' to 12650', pumping 84 gpm w/ 660 psi. No indication of cement. 01:15 03:30 2.25 12,650 12,650 PROD1 CEMEN "CIRC XT Circulate and condtion bottom's up. Pumping 168 gpm w/ 980 psi. PU wt 215k, SO wt 120k. Observed cement contaminated mud w/ PH of 12.4 and a mud weight as high as 11.9 ppg. 03:30 06:15 2.75 12,650 12,813 PROD1 CEMEN" WASH XT Wash in the hole f/ 12650' to 12813'. Pumping 84 gpm w/ 660 psi. PU wt 220k, SO wt 120k. Tag top of cement @ 12813' w/ 7k weight while pumping. 06:15 11:30 5.25 12,660 12,813 PROD1 CEMEN "CIRC XT Circulate and condition mud @ 12813'. Pumping 210 gpm w/ 1250 psi. PU wt 220k, SO wt 120k. 11:30 11:45 0.25 12,813 12,813 PROD1 CEMEN" SFTY XT Pre job safety meeting. 11:45 12:00 0.25 12,813 12,813 PROD1 CEMEN" RURD XT Rig up to pump cement plug #2. Set back one stand - PU 5' pup and one single of drill pipe - MU headpin and cement line 12:00 12:45 0.75 12,813 12,813 PROD1 CEMEN" CMNT XT Perform cement job f/ kick off plug #2. - With tbg. tail @ 12,811' - Line up to cementers - establish circulation with 3 bbls of 12.5 ppg MudPush - Test lines to 2500 psi - pump additional 9 bbls of mudPush - Mixed and pumped 100 sxs G cmt. (18.5 bbls) 16.5 ppg 1.06 cf /sx yld. - displaced to equalization with 4 bbls of 12.5 ppg mudPush and 116.8 bbls of 11.8 ppg mud - Reciprocated pipe - PUW 220K SOW 115K - had full returns throughout - CIP @ 1241 hrs. ETOC @ 12,434' - RD cement line and head pin. 12:45 13:00 0.25 12,813 12,575 PROD1 CEMEN" TRIP XT Pull out of cement from 12813' to 12575'. PU wt 230k, SO wt 110k. 13:00 18:00 5.00 12,575 12,575 PROD1 CEMEN" CIRC XT Circulate, pumping 210 gpm w/ 1570 psi. Treat cement contaminated mud. PU wt 215k, SO wt 110k. 18:00 18:30 0.50 12,575 12,575 PROD1 CEMEN" CIRC XT Circulate, pumping 294 gpm w/ 2200 psi. Treat cement contaminated mud. PU wt 215k, SO wt 110k. Page 43 of 58 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code " Subcode T Comment 18:30 19:30 1.00 12,575 12,575 PROD1 CEMEN" CIRC XT Circulate, pumping 378 gpm w/ 3000 psi. Treat cement contaminated mud. PU wt 215k, SO wt 110k. 19:30 20:00 0.50 12,575 12,604 PROD1 CEMEN" WASH XT Wash in the hole f/ 12575' to 12604'. Pumping 84 gpm w/ 470 psi. PU wt 225k, SO wt 120k. Tag top of cement @ 12604' w/ 5k weight while pumping, increase in pump pressure to 590 psi. Tag twice to confirm. 20:00 20:15 0.25 12,604 12,583 PROD1 DRILL OTHR XT Pull up f/ 12604' to 12583', set back a stand. Blow down the top drive. 20:15 20:30 0.25 12,583 12,583 PROD1 DRILL OWFF XT Monitor well- static. 20:30 00:00 3.50 12,583 6,857 PROD1 DRILL TRIP XT Pull out of the hole f/ 12583' to 6857' on the trip tank. 11/21/2009 Continue to pull out of the hole w/ 3 -1/2" cement stinger and 4" drill pipe f/ 6857' to 944'. pre job safety meeting, rig up to lay down 3 -1/2" tubing, lay down 30 joints plus the mule shoe, pull the FMC wear bushing, install test plug, fill w/ water, test the annular to 250 psi low and 2500 psi high, hold each f/ 5 minutes, -OK, rig down testing equipment, install wear bushing, PJSM, PU /MU BHA # 7 to 95', orient, change bend of motor to 1.5 deg, upload, finish running BHA to 374', shallow test MWD -OK, run in the hole w/ 4" drill pipe to 4856', Rotate BHA through the TAM port collar @ 4902', continue to run in the hole from 4951' to 12302', PJSM, slip and cut 60' of drilling line . • , ' . - ' • ' , • ' , • ... : u-, n •1'' - ,u - •1 • :u -,_• bottom of window O. 12688', orient 45 left to slide to 12710'. rotate to 12730'. slide to 12738' rotate to 1274Q' @ midnight. 00:00 02:15 2.25 6,857 944 PROD1 CEMEN" TRIP XT Continue to pull out of the hole f/ 6857' to 944' on the trip tank. 02:15 02:30 0.25 944 944 PROD1 CEMEN" SFTY XT Pre job safety meeting on laying down 3 -1/2" EUE cementing stinger. 02:30 02:45 0.25 944 944 PROD1 CEMEN" RURD XT Rig up to lay down 3 -1/2" 9.3 ppg EUE tubing. 02:45 04:30 1.75 944 0 PROD1 CEMEN" PULD XT Lay down 30 joints of 3 -1/2" tubing. Calculated displacement 79 bbls, actual 87 bbls. 04:30 05:00 0.50 0 0 PROD1 DRILL BOPE XT Pull wear FMC wear bushing. Install test plug. 05:00 06:30 1.50 0 0 PROD1 DRILL BOPE XT PJSM. Fill stack w/ water. Test annular to 250 psi low and 2500 psi high. Work air out of system. Hold each test 5 minutes. 06:30 07:00 0.50 0 0 PROD1 DRILL BOPE XT Pull FMC test plug, install FMC wear bushing (ID 7 ") 07:00 07:15 0.25 0 0 PROD1 DRILL SFTY XT Pre job safety meeting on picking up BHA #7. 07:15 07:45 0.50 0 95 PROD1 DRILL PULD XT PU /MU BHA #7. PU /MU bit, mtr, float sub, stabilizer. Adjust motor f/ 1.22 to 1.5 deg bend. PU MWD tools, Orient to motor. 07:45 08:15 0.50 95 95 PROD1 DRILL PULD XT Upload MWD. 08:15 09:00 0.75 95 374 PROD1 DRILL TRIP XT Run in the hole w/ flex collars, HWDP and jars to 374' 09:00 09:15 0.25 374 374 PROD1 DRILL DHEQ XT Shallow test MWD, pumping 200 gpm w/ 1020 psi. 09:15 11:30 2.25 374 4,856 PROD1 DRILL TRIP XT Run in the hole w/ BHA #7 on 4" drill pipe f/ 374' to 4856'. Fill pipe every 20 stands. PU wt 138k, SO wt 100k. 11:30 12:00 0.50 4,856 4,951 PROD1 DRILL REAM XT Ream through TAM port collar w/ BHA. (TAM @ 4902') Page 44 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:00 3.00 4,951 12,302 PROD1 DRILL TRIP XT Continue to trip in the hole w/ 4" drill pipe f/ 4951' to 12302'. 15:00 15:15 0.25 12,302 12,302 PROD1 DRILL SFTY XT Pre job safety meeting on slip and cut drilling line. 15:15 16:30 1.25 12,302 12,302 PROD1 RIGMNT SVRG XT Slip and cut 60' of 1 -3/8" drilling line.I 16:30 16:45 0.25 12,302 12,587 PROD1 DRILL TRIP XT Continue to trip in the hole w/ 4" drill pipe f/ 123021' to 12587'. 16:45 18:00 1.25 12,587 12,688 PROD1 DRILL WASH XT Wash down f/ 12587' to tag top of cement (KOP #2) @ 12604', Wash to bottom of window @ 12688'. 18:00 00:00 6.00 12,688 12,740 PROD1 DRILL REAM XT Orient to 45 deg left to kick off of whipstock, slide to 12710', rotate to 12730', slide to 12738', rotate to 12740'. 11/22/2009 Continue to sidetrack away from old hole. Directional drill 6 -3/4" hole w/ 1.50 deg bend motor from 12740' to 12968'. Weight on bit 10 to 25k. Pumping 290 to 300 gpm w/ 3580 to 3440 psi, Rotate 30 to 80 rpm w/ 14k ft Ibs on and 14.5 k ft Ibs off bottom. PU wt 242k, SO wt 120k, Rot wt 167k. ART = 6.31 hrs, AST = 1.48 hrs. Total bit hours 12.32 hrs Note: While drilling @ 12745'- cuttings at the shakers f/ 12739'- observed to be 10% formation While drilling @ 12748'- cuttings at the shakers f/ 12740'- observed to be 30% formation While drilling @ 12765'- cuttings at the shakers f/ 12753'- observed to be 80% formation Performed mud swap while drilling @ 12770', swapping f/ 11.6 ppg to 11.4 ppg LSND mud. First good survey was at 12880.38 -- 66.87 deg, 310.03 Azmuith Directional drill 6 -3/4" hole w/ 1.50 deg bend motor from 12968' to 13390'. Weight on bit 8 to 22k. Pumping 300 gpm w/ 3590 psi, Rotate 80 rpm w/ 15k ft Ibs on and 15 k ft Ibs off bottom. PU wt 235k, SO wt 122k, Rot wt 170k. ART = 5.33 hrs, AST = 1.04 hrs. Total bit hours 20.06 hrs. 00:00 12:00 12.00 12,740 12,968 PROD1 DRILL DDRL XT Continue to sidetrack away from old hole. Directional drill 6 -3/4" hole w/ 1.50 deg bend motor from 12740' to 12968'. Weight on bit 10 to 25k. Pumping 290 to 300 gpm w/ 3580 to 3440 psi, Rotate 30 to 80 rpm w/ 14k ft Ibs on and 14.5 k ft Ibs off bottom. PU wt 242k, SO wt 120k, Rot wt 167k. ART = 6.31 hrs, AST = 1.48 hrs. Total bit hours 12.32 hrs Note: While drilling @ 12745' - cuttings at the shakers f/ 12739' - observed to be 10% formation While drilling @ 12748' - cuttings at the shakers f/ 12740' - observed to be 30% formation While drilling @ 12765' - cuttings at the shakers f/ 12753'- observed to be 80% formation Performed mud swap while drilling @ 12770', swapping f/ 11.6 ppg to 11.4 ppg LSND mud. First good survey was at 12880.38 - -- 66.87 deg, 310.03 Azmuith Page 45 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 12,968 13,020 PROD1 DRILL DDRL XT Drilling w/ 6 -3/4" bit and 5" motor w/ 1.5 deg bend. Directional drill 6 -3/4" hole w/ 1.50 deg bend motor from 12968' to 13020'. Weight on bit 14 to 22k. Pumping 300 gpm w/ 3550 psi, Rotate 80 rpm w/ 15.5k ft Ibs on and 15 k ft Ibs off bottom. PU wt 245k, SO wt 120k, Rot wt 168k. ART = 1.37 hrs, AST = 0 hrs. Total bit hours 13.69 hrs 13:30 00:00 10.50 13,020 13,390 PROD1 DRILL DDRL X Drilling w/ 6 -3/4" bit and 5" motor w/ 1.5 deg bend. Directional drill 6 -3/4" hole w/ 1.50 deg bend motor from 13020' to 13390'. Weight on bit 8 to 22k. Pumping 300 gpm w/ 3590 psi, Rotate 80 rpm w/ 15k ft Ibs on and 15 k ft Ibs off bottom. PU wt 235k, SO wt 122k, Rot wt 170k. ART = 5.33 hrs, AST = 1.04 hrs. Total bit hours 20.06 hrs. Pumped 35 bbl sweeps to aid in bit cleaning @ 13180' (7 ppb nut plug medium, 1.25 ppb Desco). Added Lube 776 f/ torque and drag. 11/23/2009 Directional drill 6 -3/4" hole w/ 1.50 deg bend motor from 13390' to 13462' (unable to transfer weight to bit), Backream f/ 12462' to 12895' (BOW 12688', TOW 12575'), orient motor to 45 deg left, pull into 7 -5/8" casing, monitor well, POOH on trip tank f/12683' to 10775', pump dry job, continue to pull out f/ 10775' to 374', monitor well- static, set back HWDP, jars and flex collars, break off bit, download MWD, lay down BHA, drain stack, pull FMC wear bushing. install FMC test alua, rip up to test BOPE, Test BOPE. of test waived by AOGCC inspector Chuck Scheve. Chart tests, hold each test 5 minutes. Test w/ 4" test joint. Test annular, to 250 psi low and 2500 psi high. Test top and bottom pipe rams (3 -1/2" x 6" variables) to 250 psi low and 3500 psi high. Test top drive IBOP and manual IBOP to 250 and 3500 psi. Test floor IBOP and full open valve to 250 psi low and 3500 psi high. Test all valves in the choke manifold, kill) line and choke line valves to 250 psi low and 3500 psi high. Test 4" Demco valve on the kill line /mud line to 250 psi low and 3500 psi high.Test accumulator: initial pressure 3000 psi, after closing 1650 psi, 200 psi build up in 28 seconds, final pressure build up 2 minutes 41 seconds. Test blind rams to 250 psi low and 3500 psi high. 00:00 04:45 4.75 13,390 13,462 PROD1 DRILL DDRL X Directional drill 6 -3/4" hole w/ 1.50 deg bend motor from 13390' to 13462'. Weight on bit 12 to 20k. Pumping 300 gpm w/ 3580 psi, Rotate 80 rpm w/ 14.5k ft Ibs on and 13.5 k ft Ibs off bottom. PU wt 238k, SO wt 125k, Rot wt 170k. ART = 2.15 hrs, AST = .92 hrs. Total bit hours 23.13 hrs. Note: Pumped nut plug sweeps w/ lubricants while drilling @ 13458' & 13460' to aid in bit balling. Decision to pull out of hole f/ slow rate of penetration/ weight transfer. 04:45 06:45 2.00 13,462 12,895 PROD1 DRILL REAM XT Backream out from 13462' to 12,895' (BOW @ 12688', TOW 12675') 300 gpm / 3260 psi / 80 rpm @ 13.5 K ft/lbs Page 46 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:15 0.50 12,895 12,683 PROD1 DRILL TRIP XT Orient motor to 45 deg left, pull into 7 -5/8" casing to 12,683' no problems entering window. 07:15 07:30 0.25 12,683 12,683 PROD1 DRILL OWFF XT Monitor well, static - Line up trip tank 07:30 09:30 2.00 12,683 10,775 PROD1 DRILL TRIP XT Pull out of the hole on the trip tank from 12,683' to 10,775' - hole taking proper displacement 09:30 09:45 0.25 10,775 10,775 PROD1 DRILL CIRC XT Pump dry job - blow down top drive 09:45 16:15 6.50 10,775 374 PROD1 DRILL TRIP XT Pull out of the hole on the trip tank from 10,775' to 374'. 16:15 16:30 0.25 374 374 PROD1 DRILL OWFF XT Monitor well 16:30 17:00 0.50 374 95 PROD1 DRILL TRIP XT Set back Heavy weight drill pipe w/ jars and one stand of 4 -3/4" flex drill collars, break bit. 17:00 18:00 1.00 95 95 PROD1 DRILL PULD XT Download Sperry Sun MWD. Clean rig floor. 18:00 19:00 1.00 95 0 PROD1 DRILL PULD XT Lay down Sperry MWD and 1.5 deg motor. 19:00 19:30 0.50 0 PROD1 DRILL PULD XT Bring GeoSpan skid to rig floor, bring two 6 -3/4" bits to the floor f/ evaluation comparison. 19:30 20:00 0.50 0 0 PROD1 DRILL BOPE P Drain stack, pull FMC wear bushing (7" ID). 20:00 20:30 0.50 0 0 PROD1 DRILL RURD P Install FMC test plug. Rig up to test. 20:30 00:00 3.50 0 0 PROD1 DRILL BOPE P Test BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Chart tests, hold each test 5 minutes. Test w/ 4" test joint. Test annular, to 250 psi low and 2500 psi high. Test top and bottom pipe rams (3 -1/2" x 6" variables) to 250 psi low and 3500 psi high. Test top drive IBOP and manual IBOP to 250 and 3500 psi. Test floor IBOP and full open valve to 250 psi low and 3500 psi high. Test all valves in the choke manifold, kill) line and choke line valves to 250 psi low and 3500 psi high. Test 4" Demco valve on the kill line /mud line to 250 psi low and 3500 psi high.Test accumulator: initial pressure 3000 psi, after closing 1650 psi, 200 psi build up in 28 seconds, final pressure build up 2 minutes 41 seconds. Test blind rams to 250 psi low and 3500 psi high. Page 47 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/24/2009 24 hr Summary Continue to test BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Chart tests, hold each test 5 minutes. Test w/ 4 -1/2" test joint, then 3 -1/2" test joint. Test annular, to 250 psi low and 2500 psi high. Test top and bottom pipe rams (3 -1/2" x 6" variables) to 250 psi low and 3500 psi high. Remove 3 -1/2" test joint/ test plug, drain stack, install FMC (7" ID) wear bushing, PJSM, PU/MU BHA #8 (GeoPilot) to 90', upload MWD, continue to build BHA #8 to 370', Shallow pulse test MWD, test Geospan skid to 3000 psi, continue to run in the hole w/ BHA #8 on 4" drill pipe to 4851', rotate f/ 4851' to 5042' (TAM port collar @ 4902'), continue trip in to 8003', PJSM, adjust top drive rails to center top drive- better- over the rotary table stump, continue trip in f/ 8003' to 13250', wash and ream f/ 13250' to 13462', directional drill 6 -3/4" hole f/ 13462' to 13822'. 00:00 01:45 1.75 0 0 PROD1 DRILL BOPE P Continue to test BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Chart tests, hold each test 5 minutes. Test w/ 4 -1/2" test joint, then 3-1/2" test joint. Test annular, to 250 psi low and 2500 psi high. Test top and bottom pipe rams (3 -1/2" x 6" variables) to 250 psi low and 3500 psi high. 01:45 02:00 0.25 0 0 PROD1 DRILL BOPE P Remove 3 -1/2" test joint. Drain stack. Install FMC 7" ID wear bushing. Blow down choke manifold, kill line and choke line. 02:00 02:15 0.25 0 0 PROD1 DRILL SFTY XT Pre job safety meeting on picking up BHA #8 (Geopilot assembly). 02:15 04:00 1.75 0 90 PROD1 DRILL PULD XT Pickup BHA #8 to 90'. 04:00 05:00 1.00 90 90 PROD1 DRILL PULD XT Upload Sperry MWD. 05:00 05:30 0.50 90 370 PROD1 DRILL PULD XT Continue to make up BHA #8 f/ 90' to 370'. 05:30 05:45 0.25 370 370 PROD1 DRILL DHEQ XT Pulse test MWD. Pumping 238 gpm w/ 944 psi. Test Geospan skid to 3000 psi. 05:45 08:00 2.25 370 4,851 PROD1 DRILL TRIP XT Continue to run in the hole w/ 4" drill pipe f/ 370' to 4851'. Fill pipe every 20 stands. 08:00 08:30 0.50 4,851 5,042 PROD1 DRILL REAM XT Rotate 20 rpm w/ 6k ft Ibs of torque f/ 4851' to 5042'. (TAM port collar © 4902'). 08:30 10:15 1.75 5,042 8,003 PROD1 DRILL TRIP XT Continue to run in the hole w/ 4" drill pipe f/ 5042' to 8003'. Fill pipe every 20 stands. 10:15 10:30 0.25 8,003 8,003 PROD1 DRILL SFTY XT Pre job safety meeting on centering top drive over the ceneter of rotary table. 10:30 12:00 1.50 8,003 8,003 PROD1 RIGMNT SVRG XT Adjust top drive rails w/ shims. Trying to improve screwing into rotary table stump. 12:00 15:00 3.00 8,003 13,250 PROD1 DRILL TRIP XT Continue to run in the hole w/ 4" drill pipe f/ 8003' to 13250'. Fill pipe every 20 stands. 15:00 16:30 1.50 13,250 13,462 PROD1 DRILL REAM XT Wash and ream from 13250' to 13462'. Pumping 275 gpm w/ 2820 psi. Rotate 110 rpm w/ 15k ft Ibs of torque. Page 48 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 00:00 7.50 13,462 13,822 PROD1 DRILL DDRL X Directional drill 6 -3/4" hole w/ GeoPilot from 13462' to 13822'. Weight on bit 12 to 18k. Pumping 300 gpm w/ 3060 psi, Rotate 120 rpm w/ 16.5k ft lbs on and 12.5 k ft Ibs off bottom. PU wt 240k, SO wt 130k, Rot wt 174k. ART = 5.6 hrs, Total bit hours 5.6 hrs. 11/25/2009 PJSM on changing swivel packing. Stand back a stand to 13727'. Rig up and circulate w/ 2" line, pumping 126 gpm w/ 900 psi. Change swivel packing, test to 3500 psi. Continue to directional drill 6 -3/4" hole f/ 13822' to 14775'. 00:00 00:15 0.25 13,822 13,822 PROD1 DRILL SFTY X Pre job safety meeting on chnaging wash pipe packing. 00:15 00:30 0.25 13,822 13,727 PROD1 DRILL TRIP XT Stand back a stand to work on swivel packing. 00:30 00:45 0.25 13,727 13,727 PROD1 DRILL CIRC XT Rig up to circulate w/ headpin and 2" hose. Circulate while changing out washpipe packing, pumping 126 qpm w/ 900 psi. 00:45 01:15 0.50 13,727 13,822 PROD1 DRILL SVRG XT Change out swivel packing, test to 3500 psi -OK. Trip back a stand to bottom. 01:15 12:00 10.75 13,822 14,298 PROD1 DRILL DDRL X Directional drill 6 -3/4" hole w/ GeoPilot from 13822' to 14298'. Weight on bit 12 to 18k. Pumping 300 gpm w/ 3060 psi, Rotate 120 rpm w/ 16.5k ft lbs on and 13 k ft lbs off bottom. PU wt 240k, SO wt 130k, Rot wt 175k. ART = 7.5 hrs, Total bit hours 13.1 hrs. Note: Pumped 40 bbl nut plug sweep (5ppb) w/ 15 gals screenklean @ 14125'. 12:00 00:00 12.00 14,298 14,775 PROD1 DRILL DDRL X Directional drill 6 -3/4" hole w/ GeoPilot from 14298' to 14775'. Weight on bit 8 to 12k. Pumping 300 gpm w/ 3060 to 3350 psi, Rotate 120 rpm w/ 17 to 12.5k ft Ibs on and 13 to 11.5 k ft lbs off bottom. PU wt 230k, SO wt 140k, Rot wt 182k. ART = 8.64 hrs, Total bit hours 21.74 hrs. Note: Pumped nut plug sweep (5 ppb plus 15 gal screenkleen) @ 14460', dilution f/ HRZ 550 bbls(Inhibicol @ 5 %), nut plug sweep (5 ppb plus 15 gal screenkleen) @ 14662' and 14690'. 11/26/2009 Continue to directional drill 6 -3/4" hole f/ 14775' to 15088', mud line in pump room washed at flange of center pulsation dampner (Spill of 15 gal, 10 in room -5 gal outside), clean up spill, stand back a stand, blow down the top drive, PJSM, remove pulsation dampner, install blind flange, test to 4000 psi, make top drive connection, ream f/ 15061' to 15151', continue to drill 6 -3/4" hole from 15088' to 15539' (7196' TVD). Page 49 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase , Code '_ Subcode T Comment 00:00 06:30 6.50 14,775 15,088 PROD1 DRILL DDRL X Directional drill 6 -3/4" hole w/ GeoPilot from 14775' to 15088'. Weight on bit 8 to 12k. Pumping 295 gpm w/ 3350 psi, Rotate 120 rpm w/ 12.5k ft lbs on and 12 k ft lbs off bottom. PU wt 225k, SO wt 140k, Rot wt 184k. ART = 5.72 hrs, Total bit hours 27.46 hrs. 06:30 07:00 0.50 15,088 15,061 PROD1 RIGMNT TRIP XT Wash out in mud line in the pump room. Washed center pulsation dampner (Hydril K -20) bottom flange. Set back a stand to 15061'. Initiate spill clean up. Spill of 15 gallons, 10 in pump room, 5 gallons outside of pump room door. 07:00 07:15 0.25 15,061 15,061 PROD1 RIGMN1 RGRP XT Blow down the Top drive. Continue spill clean up. 07:15 07:30 0.25 15,061 15,061 PROD1 RIGMNT SFTY XT Pre job safety meeting on removing center pulsation dampner on hi pressure mud line in the pump room. Continue spill clean up. 07:30 10:00 2.50 15,061 15,061 PROD1 RIGMNT RGRP XT Remove Hydril K -20 pulsation dampner, install blind flange, test to 4000 psi. Continue spill clean up. 10:00 10:15 0.25 15,061 15,088 PROD1 RIGMN1 REAM XT Make a top drive connection, wash and ream f/ 15061' to bottom @ 15088' 10:15 12:00 1.75 15,088 15,151 PROD1 DRILL DDRL X Directional drill 6 -3/4" hole w/ GeoPilot from 15088' to 15151'. Weight on bit 8 to 12k. Pumping 295 gpm w/ 3350 psi, Rotate 120 rpm w/ 12.5k ft lbs on and 12 k ft lbs off bottom. PU wt 225k, SO wt 140k, Rot wt 184k. ART = 1.16 hrs, Total bit hours 28.62 hrs. 12:00 00:00 12.00 15,151 15,539 PROD1 DRILL DDRL X Directional drill 6 -3/4" hole w/ GeoPilot from 15151' to 15539'. Weight on bit 8 to 12k. Pumping 295 gpm w/ 3350 psi, Rotate 120 rpm w/ 12.5k ft lbs on and 12 k ft lbs off bottom. PU wt 225k, SO wt 140k, Rot wt 184k. ART = 9.49 hrs, Total bit hours 38.11 hrs. Note: TD'd 6 -3/4" production hole @ 15769' 11/27/09 @ 0435 hrs. 11/27/2009 Continue to drill 6 -3/4" hole from 15539' to 15769' (7298' TVD), circulate 3 bottom's up, backream to 14679' (HRZ top @ 14732'), monitor well- static, trip in the hole, circulate and condtion mud f/ liner (circulate 2 bottom's up), pump casing running pill, pull out of the hole spotting casing running pill (Casing running pill consists of: 55 bbls 11.6 ppb LSND w/ Inhibycol, 5ppb Sack Black, 5ppb Alpine Beads, 5ppb SafeCarb 20, 5ppb Safe Carb 250, .5ppb additional Flowzan) in the open hole 15769' to 14500' (above HRZ), continue to pump out of the hole to 12583', drop a 2.38" rabbit w/ 120' of wire on stand #130, monitor well- static, blow down Sperry Sun GeoSpan skid and remove f/ floor, weight up f/ 11.6 ppg to 11.8 ppg f/ trip margin. Page 50 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:30 4.50 15,539 15,769 PROD1 DRILL DDRL X Directional drill 6 -3/4" hole w/ GeoPilot from 15539' to 15769'. Weight on bit 6 to 10k. Pumping 2253 gpm w/ 2880 psi, Rotate 110 rpm w/ 13k ft lbs on and 12 k ft lbs off bottom. PU wt 237k, SO wt 145k, Rot wt 190k. ART = 3.51 hrs, Total bit hours 41.62 hrs. 04:30 05:00 0.50 15,769 15,769 PROD1 DRILL CIRC X Obtain final survey @ TD, 15769' (7298' TVD) 63.64 deg 320.07 Azimuth. Obtain final torque and drag readings. PU wt 237k, SO wt 145k, Rot wt 190k, rot torque 12k off bottom. 05:00 09:00 4.00 15,769 15,252 PROD1 DRILL CIRC P Circulate and condition mud f/ trip out. Pumping 253 to 300 gpm w/ 2830 to 3450 psi, rotate 110 to 90 rpm w/ 13k to 12.5k ft Ibs of torque. ECD's 13.1 ppg. Backream, setting back a stand every 40 minutes. 09:00 12:00 3.00 15,252 14,679 PROD1 DRILL REAM P Backream out of the hole f/ 15252' to 14679', (top of HRZ @ 14732'). Pumping 300 gpm w/ 3460 psi, rotate 90 rpm w/ 12k ft Ibs of torque. ECD's 13.1 ppg. 12:00 12:15 0.25 14,679 14,679 PROD1 DRILL OWFF P Monitor well- static. Blow down the top drive. 12:15 12:30 0.25 14,679 15,769 PROD1 DRILL TRIP P Trip in the hole to TD @ 15769'. PU wt 235k, SO wt 140k. 12:30 12:45 0.25 15,769 15,769 PROD1 DRILL OWFF P Monitor well- static. 12:45 15:45 3.00 15,769 15,347 PROD1 DRILL CIRC P Circulate and condition mud f/ liner, circulate 2 bottom's up. Pumping 285 gpm w/ 3280 psi, rotating 90 rpm w/ 12k ft Ibs of torque. Stand back a stand every 30 minutes to 15347' 15:45 16:00 0.25 15,347 15,769 PROD1 DRILL TRIP P Trip in the hole to TD @ 15769'. 16:00 16:30 0.50 15,769 15,769 PROD1 DRILL CIRC P Make a top drive connection. Pump casing running pill into the drill pipe. 16:30 18:30 2.00 15,769 14,500 PROD1 DRILL TRIP P Pull out of the hole spotting the casing running pill in the open hole (15769' to 14500') above HRZ. Pumping 2 bpm w/ 850 psi, while pulling pipe @ 23' min. Note: Casing running pill consists of: 55 bbls 11.6 ppb LSND w/ Inhibycol, 5ppb Sack Black, 5ppb Alpine Beads, 5ppb SafeCarb 20, 5ppb Safe Carb 250, .5ppb additional Flowzan. 18:30 21:45 3.25 14,500 12,583 PROD1 DRILL TRIP P Continue to pump out of the hole f/ 14500' to 12583', pumping 3 bpm w/ 1060 psi, pulling speed of 23' /minute. PU wt 200k w/ pumps. Note: Dropped a 2.38" OD hollow rabbit w/ 120' slickline wire, on stand #130 (12774'). Page 51 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 22:00 0.25 12,583 12,583 PROD1 DRILL OWFF P Monitor well- static. 22:00 00:00 2.00 12,583 12,583 PROD1 DRILL CIRC P Weight up f/ 11.6 ppg to 11.8 ppg f/ trip margin above the window. Pumping 255 gpm w/ 2480 psi, rotate 90 rpm w/ 12k ft Ibs of torque. ECD's 13.23 ppq. 11/28/2009 Monitor well- static, blow down the top drive, pull out of the hole f/ 12583' to 11057' monitoring returns on the trip tank, pump a 15 bbl dry job, continue to pull out of the hole f/ 11057' to 8194', repair 1" hydraulic hose on rig floor, continue to pull out of the hole f/ 8194' to the BHA @ 370' monitoring returns on the trip tank, monitor well- static, stand back HWDP and jars, stand back flex collars, download MWD, service geopilot, break bit, lay down geopilot and MWD, clear floor, rig up to run 4 -1/2" 12.6 ppf SLHT L -80 liner, PJSM, Pickup /make up 4 -1/2" shoe track (IBT -m), service rig, continue to run 4 -1/2" liner f/ 106.22' to 3325' per detail, MU Baker seal bore extension, change elevators to 3 -1/2" dp elevators, PU /MU Baker liner hanger and ZXP liner top packer. Torque 6000 ft Ibs on hanger connection 5 -1/2" BTC -TKC. Mix pal mix, pour in top of liner hanger then attach debris cover, allow to set. Run a stand of 4" drill P i P top e. Make a to drive connection. PU wt 100k, SO wt 95k. Circulate surface to surface. Pumping 3 bpm w/ 210 psi, 5 bpm w/ 320 psi. Circulate 150 bbls. Blow down the top drive. Install air slips and stripper rubber. Continue running 4 "drill pipe from the derrick (30' /minute). Fill every stand on the fly. Top off every 5 stands. Record PU, SO and Rot wt's every 20 stands. 9 stands in the hole at midnight. 00:00 00:15 0.25 12,583 12,583 PROD1 DRILL OWFF P Monitor well- static. Blow down the top drive. 00:15 02:15 2.00 12,583 11,057 PROD1 DRILL TRIP P Trip out of the hole f/ 12583' to 11057', monitor returns on the trip tank. 02:15 02:30 0.25 11,057 11,057 PROD1 DRILL CIRC P Pump a 15 bbl dry job, 13 ppb. 02:30 05:00 2.50 11,057 8,194 PROD1 DRILL TRIP P Continue trip out of the hole f/ 11057' to 8194', monitor returns on the trip tank. 05:00 06:00 1.00 8,194 8,194 PROD1 RIGMNT RGRP T Replace a 1" hydraulic hose. Hose location by 4 ton LANTEC tugger on the off drillers side by the derrick leg. Hose failed leaking approx a pint of hydraulic oil to secondary containment. 06:00 12:00 6.00 8,194 370 PROD1 DRILL TRIP P Continue trip out of the hole f/ 8194' to 370', monitor returns on the trip tank. 12:00 12:15 0.25 370 370 PROD1 DRILL OWFF P Monitor well- static. 12:15 12:30 0.25 370 90 PROD1 DRILL TRIP P Continue trip out of the hole f/ 370' to 90', monitor returns on the trip tank. Stand back two stands of 4" HWDP. Change elevators, lay down non mag flex collars. 12:30 13:30 1.00 90 90 PROD1 DRILL PULD P Download MWD. 13:30 14:00 0.50 90 90 PROD1 DRILL TRIP P Service geopilot, break bit. 14:00 14:30 0.50 0 0 PROD1 DRILL PULD P Lay down BHA #8. Note: Calculated fill 83.53 bbls, actual 97.5 bbls. 14:30 15:00 0.50 0 0 PROD1 DRILL PULD P Clean and clear rig floor. 15:00 16:15 1.25 0 0 COMPZ CASING RURD P Rig up to run 4 -1/2" 12.6 ppf SLHT L -80 liner. 16 :15 16:30 0.25 0 0 COMPZ CASING SFTY P Pre job safety meeting on runnning liner. Page 52 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:00 0.50 0 0 COMPZ CASING SVRG P Service rig, top drive and drawworks. 17:00 20:45 3.75 0 3,325 COMPZ CASING PULD P Pick up /make up/ run in w/ first 3 joints of liner (4 -1/2" 12.6 ppf L -80 IBT -m). Float shoe, Float collar and landing collar are IBTas well, then crossover to 4 -1/2" 12.6 ppf SLHT L -80. Baker locked to above landing collar. Continue running liner to jt #83. Run a total of 70 4 -1/2" x 6 -1/8" 3 rib hydraforms: jt # 3 thru 70, then jt #79 and #80. MU torque 5000 ft Ibs on SLHT. 20:45 21:45 1.00 3,325 3,388 COMPZ CASING PULD P MU Baker seal bore extension, change elevators to 3 -1/2" dp elevators, PU /MU Baker liner hanger and ZXP liner top packer. Torque 6000 ft Ibs on hanger connection 5 -1/2" BTC -TKC. 21:45 22:00 0.25 3,388 3,388 COMPZ CASING OTHR P Mix pal mix, pour in top of liner hanger then attach debris cover, allow to set. 22:00 22:15 0.25 3,388 3,479 COMPZ CASING RUNL P Run a stand of 4" drill pipe. Make a top drive connection. PU wt 100k, SO wt 95k. 22:15 22:45 0.50 3,479 3,479 COMPZ CASING CIRC P Circulate surface to surface. Pumping 3 bpm w/ 210 psi, 5 bpm w/ 320 psi. Circulate 150 bbls. 22:45 23:00 0.25 3,479 3,479 COMPZ CASING OTHR P Blow down the top drive. Install air slips and stripper rubber. 23:00 00:00 1.00 3,479 4,243 COMPZ CASING RUNL P Continue running 4 "drill pipe from the derrick (30' /minute). Fill every stand on the fly. Top off every 5 stands. Record PU, SO and Rot wt's every 20 stands. 9 stands in the hole at midnight. 11/29/2009 Run 4 -1/2" liner: Con't running 4 "drill pipe f/ the derrick (30' /minute). Fill every stand on the fly. Top off every 5 stands. Record PU, SO and Rot wt's every 20 stands. Con't f/ 4235' to 6245 shoe depth (30 stands). CBU, stage pumps up f/ 3 bpm w/ 400 psi to 5 bpm w/ 570 psi. Pump 200 bbls. Blow down the top drive. Con't running 4 "drill pipe f/ 6245' to 9111' shoe depth (60 stands). CBU, stage pumps up f/ 2 bpm w/ 400 psi to 5 bpm w/ 890 psi. Pump 275 bbls. Blow down the top drive. Con't running 4 "drill pipe from 9111' to 12643' shoe depth (97 stands). CBU, stage pumps up f/ 2 bpm w/ 590 psi to 5 bpm w/ 1160 psi. Pump 370 bbls. Blow down the top drive. PU make up Baker cementing head from pipe shed, torque connections, lay down head. Con't running 4 "drill pipe from the derrick (30' /minute), f/ 12643' to 15769' shoe depth, Tag bottom 5.6' deep. 71' of stand 130 stand in the hole. Lay down a single ( on stand #130, pull a double, install 15.03' pup joint, make up Baker top drive cementing head,,Start circulating to condition mud and hole f/ cement. Initial pump rate of 2 bpm w/ 920 psi, stage up rate, 3 bpm w/ 1180 psi, 4 bpm w/ 1360 psi, 5 bpm w/ 1550 initial and final of 1460 psi. Pumped 782 bbls at midnight. Highest MW out was 12.8 ppg. 00:00 02:15 2.25 4,243 6,245 COMPZ CASING RUNL P Continue running 4 "drill pipe from the derrick (30' /minute), f/ 4235' to 6245' shoe depth, 30 stands in the hole . Fill every stand on the fly. Top off every 5 stands. Record PU, SO and Rot wt's every 20 stands. 02:15 03:00 0.75 6,245 6,245 COMPZ CASING CIRC P Circulate bottom's up, stage pumps up f/ 3 bpm w/ 400 psi to 5 bpm w/ 570 psi. Pump 200 bbls. Page 53 of 58 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:15 0.25 6,245 6,245 COMPZ CASING OTHR P Blow down the top drive. 03:15 06:45 3.50 6,245 9,111 COMPZ CASING RUNL P Continue running 4 "drill pipe from the derrick (30' /minute), f/ 6245' to 9111' shoe depth, 60 stands in the hole. Fill every stand on the fly. Top off every 5 stands. PU wt 160k, SO wt 120k, Rot wt 140k, Rot 30 rpm w/ 8k ft Ibs of torque. 06:45 08:15 1.50 9,111 9,111 COMPZ CASING CIRC P Circulate bottom's up, stage pumps up f/ 2 bpm w/ 400 psi to 5 bpm w/ 890 psi. Pump 275 bbls. 08:15 08:30 0.25 9,111 9,111 COMPZ CASING OTHR P Blow down the top drive. 08:30 12:30 4.00 9,111 12,643 COMPZ CASING RUNL P Continue running 4 "drill pipe from the derrick (30' /minute), f/ 9111' to 12643' shoe depth, 97 stands in the hole. Fill every stand on the fly. Top off every 5 stands. Record PU, SO and Rot wt's every 20 stands. 12:30 15:00 2.50 12,643 12,643 COMPZ CASING CIRC P Circulate bottom's up, stage pumps up f/ 2 bpm w/ 590 psi to 5 bpm w/ 1160 psi. Pump 370 bbls. 15:00 15:15 0.25 12,643 12,643 COMPZ CASING OTHR P Blow down the top drive. 15:15 16:15 1.00 12,643 12,643 COMPZ CASING PULD P Pick up /Make up Baker cement swivel head, torque connections, lay down head.. 16:15 20:00 3.75 12,643 15,769 COMPZ CASING RUNL P Continue running 4 "drill pipe from the derrick (30' /minute), f/ 12643' to 15769' shoe depth, Tag bottom 5.6' deep. 71' of stand 130 stand in the hole. Fill every stand on the fly. Top off every 5 stands. Record PU, SO and Rot wt's every 20 stands. 20:00 21:00 1.00 15,769 15,769 COMPZ CASING PULD P Lay down a single on stand #130, pull a double, install 15.03' pup joint, make up Baker top drive cementing head. 21:00 00:00 3.00 15,769 15,769 COMPZ CEMEN' P Start circulating to condition mud and hole f/ cement. Initial pump rate of 2 bpm w/ 920 psi, stage up rate, 3 bpm w/ 1180 psi, 4 bpm w/ 1360 psi, 5 bpm w/ 1550 initial and final of 1460 psi. Pumped 782 bbls at midnight. Highest MW out was 12.8 PPg. Page 54 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase ''Code Subcode T Comment 11/30/2009 24 hr summary Con't to circulate and condition mud and hole for cement, 6 bpm w/ 1850 psi. Pumped 1186 bbls total. 11.6 ppg, Yeild point 23. Pre job safety meeting on rigging up cementing equipment to Baker head. Cement liner per program: Dowell pump 10 bbls CW 100, test lines to 5000 psi, pump another 20 bbls CW 100 for a total of 30 bbls (8.6 ppg), mix and pump 40 bbls MudPush (12.5 ppg) @ 5 bpm w/ 1550 psi, mix and pump 123 bbls in the string of class "G" w/ additives (125 bbls mixed and pumped) ( 605 sx)(Yield 1.16 cu /ft /sx) (5.076 water/ sx) (15.8 ppg) @ 5.3 bpm w/ initial 1400 psi, final of 1300 psi, shut down. Flush lines, Rig pump mud and bump plug w/ 1500 psi, CIP @ 0406 hrs, pressure up to 4300 psi to set hanger and release running tool, Pick up 5', set down w/ dog sub on packer numerous times with and without rotation to set packer, apply 1000 psi, then pull out 44' to place tailpipe near bottom of profile in liner top packer, circulate 8 bpm w/ 1870 psi for 250 bbls, slow to 3 bpm to help identify fluids returns, increase rate to 10 bpm w/ 3340 psi, circulated 490 bbls (BU *1.3), circulated approx 6 bbls cement f/ hole. Lay down two singles and Baker cement head, lay down 15' pup joint. Pre job safety meeting on slip and cut drilling line. Slip and cut 90' of 1 -3/8" drilling line. Pull out of the hole f/ 12394' to 1944', circulate a pipe volume to balance mud, blow down the top drive, continue to pull out of the hole to Baker running tools, change elevators to 3 -1/2 ", inspect dog sub - sleeve shifted when setting packer. Continue to lay down Baker equipment. Bring Baker cement assembly from the pipe shed and break connections. Clean and clear floor, Bring FMC 4 -1/2" tubing hanger to the floor. Pull FMC 7" wear bushing, set completion wear bushing, rig up to run completion, Pre job safety meeting, Run 3 -1/2" x 4 -1/2" completion per detail to 2560'. PU wt 95k, SO wt 95k. MU tubing to 1800 ft lbs of torque on the torque guace w/ 2 -3/8" to 2 -1/2" thread loss on make up. 00:00 01:00 1.00 15,769 15,769 COMPZ CEMEN" CIRC P Continue to circulate and condition mud and hole for cement, pumping 6 bpm w/ 1850 psi. Pumped 1186 bbls total. Final weight in and out 11.6 ppg with yield pont of 23. Reciprocated 30' stroke while circulating. 01:00 01:15 0.25 15,769 15,769 COMPZ CEMEN" SFTY P Pre job safety meeting on rigging up cement equipment to Baker cement head. 01:15 02:00 0.75 15,769 15,769 COMPZ CEMEN" RURD P Rig up cementing equipment. 02:00 03:15 1.25 15,769 15,769 COMPZ CEMEN" PUCM P Cement liner per program: Dowell pump 10 bbls CW 100, test lines to 5000 psi, pump another 20 bbls CW 100 for a total of 30 bbls (8.6 ppg), mix and pump 40 bbls MudPush (12.5 ppg) @ 5 bpm w/ 1550 psi, mix and pump 123 bbls in the string of class "G" w/ additives (125 bbls mixed and pumped) ( 605 sx)(Yield 1.16 cu /ft /sx) (5.076 water/ sx) (15.8 ppg) @ 5.3 bpm w/ initial 1400 psi, final of 1300 psi, shut down. 03:15 03:30 0.25 15,769 15,769 COMPZ CEMEN" OTHR P Close bottom valve on Baker cement head. Pump through the top drive, flushing cement line to pits by pumping 25 bbls of mud through top drive back to pits. Remove cement hose and cap 2 ". Close top valve on cement head. Open bottom valve. Drop drill pipe wiper plug. Page 55 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 15,769 15,767 COMPZ CEMEN DISP P Rig displace cement: Pumping 45 bbls 11.6 ppg mud @ 6bpm, then 15 bbls water @ 3bpm w/ 390 psi, 20 bbls mud @ 6 bpm w/ 1800 to 1900 psi, 15 bbls mud @ 3 bpm w/ 670 to 700 psi, 24 bbls mud @ 5 bpm w/ 1330 to 1390 psi, slow to 3 bpm after a total of 119 bbls pumped, pump 8 bbls watching for latch up of wiper plug which was calculated at 1225 strokes (actual strokes 1198 strokes), continued pumping 36 bbls @ 4 bpm w/ 1220 to 1270 psi, slowed back to 2 bpm for final displacement to bump plug at calculated after latch up. Bumped on 1691 strokes to 1500 psi. CIP @ 0406hrs 11/30/09. Reciprocated pipe until 0402 hrs 11/30/09. Reciprocated 10' stroke during cement job and displacement. 04:00 04:45 0.75 15,767 15,767 COMPZ CEMEN" OTHR P Pressure up to 4300 psi to set hanger and release running tool. , bleed off pressure, check floats- OK. Pick up wt w/ out liner 205k, pick up 5', set down on packer numerous times with and without rotation to energize ZXP packer w/ dog sub on running tool. 04:45 05:45 1.00 15,767 12,394 COMPZ CEMEN' CIRC P Apply 1000 psi to liner string. Pull out 44' while puming slow to place tailpipe near bottom of profile in liner top packer, PU wt 205k, circulate 8 bpm w/ 1870 psi for 250 bbls , slow to 3 bpm to help identify fluids returns, increase rate to 10 bpm w/ 3330 psi, circulated 492 bbls (BU *1.3). Note: Observed mud push back to the shakers @ 3300 strokes which was calculated f/ 200' of cement above lap, so approx 6 bbls of cement was circulated from well. 05:45 06:30 0.75 12,394 12,394 COMPZ CEMEN" PULD P Lay down two singles and Baker cement head, lay down 15' pup joint. 06:30 06:45 0.25 12,394 12,394 COMPZ CEMEN" SFTY P Pre job safety meeting on slip and cut drilling line. 06:45 08:00 1.25 12,394 12,394 COMPZ CEMEN' SVRG P Slip and cut 90' of 1 -3/8" drilling line. Service top drive, calibrate TOTCO EDMS for depth control. 08:00 14:45 6.75 12,394 1,944 COMPZ CEMEN" TRIP P Pull out of the hole f/ 12394' to 1944', monitor well on the trip tank. 14:45 15:00 0.25 1,944 1,944 COMPZ CEMEN" CIRC P Circulate a pipe volume to balance mud. 15:00 15:15 0.25 1,944 1,944 COMPZ CEMEN' OTHR P Blow down the top drive. 15:15 16:00 0.75 1,944 54 COMPZ CEMEN TRIP P Continue to pull out of the hole to Baker running tools. Page 56 of 58 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:15 0.25 54 54 COMPZ CEMEN" OTHR P Change elevators to 3 -1/2 ". 16:15 16:30 0.25 54 0 COMPZ CEMEN" PULD P Pick up to inspect dog sub- sleeve was shifted when setting packer. Continue to lay down Baker equipment. 16:30 17:30 1.00 0 0 COMPZ CEMEN" PULD P Bring Baker cement assembly from the pipe shed and break connections. 17:30 18:00 0.50 0 0 COMPZ CEMEN" PULD P Clear and clean rig floor. Lay down Baker cement head. Bring FMC 4 -1/2" tubing hanger to the rig floor 18:00 18:30 0.50 0 0 COMPZ CEMEN" OTHR P Pull FMC 7" ID wear bushing. Install FMC completion running wear bushing. 18:30 19:00 0.50 0 0 COMPZ RPCOM RURD P Rig up to run completion (3 -1/2" x 4-1/2"). 19:00 19:30 0.50 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on running tubing. 19:30 00:00 4.50 0 2,560 COMPZ RPCOM RCST P Pick up/ Make up 3 -1/2" tubing per detail to 2560'. PU wt 95k, SO wt 95k. MU tubing to 1800 ft Ibs of torque on the torque guage w/ 2 -3/8" to 2 -1/2" thread loss on make up. 12/01/2009 Continue to Run 3 1/2" Upper Completion per Detail f/ 2560' - 10148' MD - Test Casing t/ 3500 Psi f/ 30 Minutes - Crossover and Continue to Run 4 1/2" Upper Completion per Detail t/ 12,288' MD - Crossover to 4" DP & Take Space Out Measurements - P/U 3, 4 1/2" IBT Pups and Space Out Completion 3' Above Locator - R/U and Displace Wellbore Fluids w/ 275 bbl Fresh Water, 30 BbI Viscosified Spacer, 425 Bbl Brine, 20 BbI Inhibited Brine, 121 Bbl Brine - P/U Tubing hanger, Terminate SSSV Control Line and Land Tubing Hanger w/ Seals 3' Above Locator w/ Tail @ 12,434' MD - RILDS and Test Tubing t/ 3500 Psi f/ 30 Minutes - Bled Tubing Pressure to 2200 Psi - Tested Tubing to Casing Annulus to 3500 Psi f/ 30 Minutes - Bled Tubing Pressure and Observed DCK -2 Valve Shear at 2800 Psi Differential - Bled the Remaining Pressure and Rigged Down 00:00 06:00 6.00 2,560 10,148 COMPZ RPCOM RCST P Continue to pick up/ Make up 3 -1/2" tubing per detail from 2560' to 10148'. PU wt 130k, SO wt 96k. Record PU and SO wt's per Rig engineer. MU tubing to 1800 ft Ibs of torque on the torque gauge w/ 2 -3/8" to 2 -1/2" thread Toss on make up. 06:00 06:45 0.75 10,148 10,148 COMPZ RPCOM RURD P Rig up to test casing to 3500 psi for 30 minutes, test casing, chart test. 06:45 07:30 0.75 10,148 10,148 COMPZ RPCOM PRTS P Test 7 -5/8" 29.6 ppf L -80 BTC -m casing and 4 -1/2" 12.6 ppf L -80 SLHT liner to 3500 psi for 30 minutes. Chart test. 07:30 08:15 0.75 10,148 10,148 COMPZ RPCOM RURD P Rig down testing equipment. 08:15 12:00 3.75 10,148 12,288 COMPZ RPCOM RCST P Continue to Run Completion as Follows: 3 1/2" EUE by 4 1/2" IBT XO, 1 jt 4 1/2" Tubing, SSSV (M /U & Test Control Line t/ 5,000 Psi), & 48 Jts of 4 1/2" Tubing 12:00 13:45 1.75 12,288 12,365 COMPZ RPCOM HOSO P Crossover to 4" DP and Measure Distance to Space Out Seal Assembly t/ 3' Above Locator - L/D DP and P/U 3 4 1/2" Pups Jts & 2 Jts of 4 1/2" Tubing Page 57 of 58 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 14:30 0.75 12,365 12,365 COMPZ RPCOM OTHR P M/U Landing Jt 'B' and Pull Tubing Running Wear Ring 14:30 15:00 0.50 12,365 12,365 COMPZ RPCOM PULD P M/U 4 1/2" IBT to 4" XT Crossover and 1 Jt of 4" DP 15:00 15:30 0.50 12,365 12,365 COMPZ RPCOM SFTY P PJSM on Displacement of Wellbore Fluids 15:30 19:15 3.75 12,365 12,365 COMPZ RPCOM DISP P Displace Wellbore Fluids as Follows: Pump 275 Bbl Fresh Water, 30 bbl High Vis Spacer, 475 Bbl Brine, 20 bbl Inhibited Brine, 121 Bbl Brine 19:15 21:00 1.75 12,365 12,434 COMPZ RPCOM HOSO P UD 4' DP adn XO, P/U Tubing Hanger and Landing Jt 'A' - Terminate SSSV Control Line - Test Line t/ 6,000 Psi - Land Hanger and RILDS - Total of 55 Stainless Steel Bands Used to Secure the Control Line 21:00 23:30 2.50 12,434 12,434 COMPZ RPCOM PRTS P Test Completion Tubing t/ 3500 psi f/ 30 Minutes - Bleed Pressure to 2200 Psi - Test Packer t/ 3500 psi f/ 30 Minutes - Bleed Tubing Pressure Observe DCK -2 Valve in GLM Shear @ 2,800 Psi Differential 23:30 00:00 0.50 12,434 12,434 COMPZ RPCOM RURD P Bleed Remaining Pressure - Rig Down Lines 12/02/2009 Install TWC, Test Hanger Seals t/ 5,000 Psi f/ 5 Minutes - N/D BOPE - N/U Tree & Test t/ 5,000 Psi - Pull TWC & Freeze Protect Well, Pumped 100 Bbl Diesel Down Annulus & Allow to U -Tube - Secure Well Head & Release Rig @ 0900 00:00 00:30 0.50 12,434 12,434 COMPZ RPCOM PRTS P Install TWC and Pressure Test Hanger Seals t/ 5,000 Psi 00:30 02:00 1.50 12,434 12,434 COMPZ WHDBO NUND P Nipple Down BOPE While Changing Saver Sub t/ 4 1/2 IF 02:00 03:30 1.50 12,434 12,434 COMPZ WHDBO NUND P N/U Tree and Test t/ 5,000 Psi f/ 5 Minutes 03:30 08:30 5.00 12,434 0 COMPZ RPCOM FRZP P Pull TWC - R/U and Freeze Protect Well t/ 2,000' TVD by Pumping 100 bbl of Diesel Down Annulus w/ Dowell Skid while Taking Returns to the Pits - Shut Down & Close Valves SITP 0, SICP 270 - Allow Fluid to U -Tube Accross the Squeeze Manifold 08:30 09:00 0.50 0 0 COMPZ RPCOM OTHR P R/D Lines and Secure Tree Release Rig @ 0900 Page 58of58 • • !. . =a t ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad CD2 -76 k 501032060300 Sperry Drilling _. Definitive Survey Report 02 December, 2009 1 ! i a F 1 is :i I F 4 i : HALLIBURTON I Sperry Drilling Services • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well CD2 -76 Project: Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Well: CD2 - 76 North Reference: - ! True Wellbore: ! CD2 - 76 Survey Calculation Method: Minimum Curvature Design: CD2 -76 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level i Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD2 - 76 Well Position +N /-S 0.00 ft Northing: 5,974,149.15 ft Latitude: 70° 20' 15.293 N +E/ -W 0.00 ft Easting: 371,170.64 ft Longitude: 151 Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 15.60ft Wellbore CD2 - 76 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (e) (nT) BGGM2007 11/13/2009 21.27 80.70 57,622 I Design CD2 - 76 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,675.00 i Vertical Section: Depth From (TVD) +N/-S +E! -W Direction 1 (ft) (ft) (ft) ( 36.67 0.00 0.00 324.00 Survey Program Date From To (ft) (ft), Survey (Wellbore) Tool Name Description Survey Date 100.00 633.00 CD2 -76PB1 (gyro) (CD2- 76PB1) CB- GYRO -SS Camera based gyro single shot 10/19/2009 672.70 12,675.00 CD2 -76PB1 (mwd) (CD2- 76PB1) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 10/20/2009 12,734.20 15,703.20 CD2 -76 (mwd) (CD2 -76) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 11/22/2009 • Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/ -W Northing Easting DLS Section (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) (01100') (ft) Survey Tool Name 36.67 0.00 0.00 36.67 -15.60 0.00 0.00 5,974,149.15 371,170.64 0.00 0.00 UNDEFINED 100.00 0.40 142.57 100.00 47.73 -0.18 0.13 5,974,148.97 371,170.77 0.63 -0.22 CB- GYRO -SS (1) 142.00 0.48 127.28 142.00 89.73 -0.40 0.36 5,974,148.75 371,171.00 0.34 -0.54 CB- GYRO -SS (1) 172.00 0,53 141.35 172.00 119.73 -0.58 0.55 5,974,148.56 371,171.18 0.44 -0.79 CB- GYRO -SS (1) 263.00 1.23 351.93 262.99 210.72 0.06 0.68 5,974,149.19 371,171.32 1.88 -0.35 CB- GYRO -SS (1) 356.00 3.73 348.51 355.90 303.63 4.01 -0.07 5,974,153.16 371,170.64 2.69 3.28 CB- GYRO -SS (1) 448.00 6.34 344.69 447.53 395.26 11.84 -2.00 5,974,161.02 371,168.84 2.86 10.76 CB- GYRO -SS (1) 541.00 8.39 341.46 539.76 487.49 23.23 -5.52 5,974,172.47 371,165.52 2.25 22.04 CB- GYRO -SS(1) 633.00 10.13 340.65 630.56 578.29 37.23 -10.33 5,974,186.55 371,160.95 1.90 36.19 CB- GYRO -SS (1) 672.70 11.19 344.87 669.58 617.31 44.24 -12.50 5,974,193.59 371,158.91 3.31 43.14 MWD +IFR- AK- CAZ -SC (2) 764.13 14.03 342.25 758.79 706.52 63.36 -18.19 5,974,212.81 371,153.54 3.17 61.95 MWD +IFR- AK- CAZ -SC (2) 856.86 15.46 342.54 848.47 796.20 85.86 -25.33 5,974,235.42 371,146.79 1.54 84.35 MWD +IFR- AK- CAZ -SC (2) 12/2/2009 1:04:13PM Page 2 COMPASS 2003.16 Build 69 • S ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD2 -76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: '' CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Well: CD2 -76 North Reference: True Weilbore: CD2 -76 Survey Calculation Method: Minimum Curvature Design: CD2 -76 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Az] TVD TVDSS +N/-S +E/- -W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 952.27 17.77 341.11 939.89 887.62 111.77 -33.86 5,974,261.47 371,138.71 2.46 110.32 MWD +IFR -AK- CAZ -SC (2) 1,047.22 21.41 343.11 1,029.33 977.06 142.07 -43.59 5,974,291.94 371,129.50 3.90 140.56 MWD +IFR -AK- CAZ -SC (2) 1,140.29 22.96 341.32 1,115.50 1,063.23 175.52 -54.34 5,974,325.57 371,119.33 1.82 173.94 MWD +IFR -AK- CAZ -SC (2) 1,237.76 24.38 335.73 1,204.78 1,152.51 211.88 -68.70 5,974,362.16 371,105.60 2.72 211.79 MWD +IFR -AK- CAZ -SC (2) 1,331.96 27.18 330.97 1,289.61 1,237.34 248.43 -87.13 5,974,399.02 371,087.79 3.69 252.20 MWD +IFR -AK- CAZ -SC (2) 1,427.39 32.40 326.99 1,372.41 1,320.14 288.96 - 111.66 5,974,439.96 371,063.97 5.85 299.40 MWD +IFR -AK- CAZ -SC (2) 1,479.91 34.24 325.94 1,416.29 1,364.02 313.00 - 127.60 5,974,464.27 371,048.45 3.67 328.22 MWD +IFR -AK- CAZ -SC (2) 1,523.20 35.37 325.93 1,451.84 1,399.57 333.47 - 141.44 5,974,484.97 371,034.96 2.61 352.92 MWD +IFR -AK- CAZ -SC (2) 1,617.86 38.28 324.49 1,527.60 1,475.33 380.04 - 173.83 5,974,532.09 371,003.38 3.21 409.63 MWD +IFR -AK- CAZ -SC (2) 1,712.90 40.56 324.16 1,601.02 1,548.75 429.06 - 209.02 5,974,581.70 370,969.03 2.41 469.98 MWD +IFR -AK- CAZ -SC (2) 1,808.35 43.69 325.59 1,671.80 1,619.53 481.43 - 245.83 5,974,634.69 370,933.13 3.43 533.98 MWD +IFR -AK- CAZ -SC (2) 1,902.26 47.49 323.99 1,737.51 1,685.24 536.21 - 284.53 5,974,690.12 370,895.39 4.23 601.04 MWD +IFR -AK- CAZ -SC (2) 1,998.67 51.67 321.90 1,800.01 1,747.74 594.74 - 328.78 5,974,749.40 370,852.16 4.64 674.40 MWD +IFR -AK- CAZ -SC (2) 2,093.17 55.51 320.64 1,856.09 1,803.82 654.04 - 376.36 5,974,809.51 370,805.60 4.20 750.35 MWD +IFR -AK- CAZ -SC (2) 2,189.59 58.05 320.91 1,908.91 1,856.64 716.53 - 427.37 5,974,872.85 370,755.68 2.64 830.88 MWD +IFR -AK- CAZ -SC (2) 2,284.69 61.64 321.42 1,956.68 1,904.41 780.57 - 478.92 5,974,937.77 370,705.24 3.80 913.00 MWD +IFR -AK- CAZ -SC (2) 2,378.58 65.62 320.38 1,998.37 1,946.10 845.83 - 531.97 5,975,003.93 370,653.32 4.35 996.98 MWD +IFR -AK- CAZ -SC (2) 2,475.53 67.74 320.43 2,036.75 1,984.48 914.43 - 588.71 5,975,073.49 370,597.78 2.19 1,085.83 MWD +IFR -AK- CAZ -SC (2) 2,570.79 65.88 320.35 2,074.26 2,021.99 981.89 - 644.53 5,975,141.89 370,543.12 1.95 1,173.21 MWD +IFR -AK- CAZ -SC (2) 2,666.31 65.73 319.91 2,113.41 2,061.14 1,048.76 - 700.39 5,975,209.70 370,488.43 0.45 1,260.14 MWD +IFR -AK- CAZ -SC (2) 2,761.50 67.51 320.11 2,151.18 2,098.91 1,115.70 - 756.53 5,975,277.59 370,433.45 1.88 1,347.30 MWD +IFR -AK- CAZ -SC (2) 2,856.69 67.56 319.95 2,187.56 2,135.29 1,183.12 - 813.04 5,975,345.96 370,378.11 0.16 1,435.06 MWD +IFR -AK- CAZ -SC (2) 2,951.75 68.29 320.43 2,223.28 2,171.01 1,250.78 - 869.44 5,975,414.58 370,322.88 0.90 1,522.95 MWD +IFR -AK- CAZ -SC (2) 3,047.09 67.89 319.32 2,258.86 2,206.59 1,318.42 - 926.44 5,975,483.18 370,267.06 1.16 1,611.17 MWD +IFR -AK- CAZ -SC (2) 3,141.95 67.54 318.90 2,294.83 2,242.56 1,384.77 - 983.90 5,975,550.51 370,210.75 0.55 1,698.63 MWD +IFR -AK- CAZ -SC (2) 3,237.72 67.65 319.74 2,331.33 2,279.06 1,451.92 - 1,041.61 5,975,618.63 370,154.21 0.82 1,786.87 MWD +IFR -AK- CAZ -SC (2) 3,332.90 67.43 319.61 2,367.70 2,315.43 1,518.98 - 1,098.54 5,975,686.65 370,098.45 0.26 1,874.58 MWD +IFR -AK- CAZ -SC (2) 3,346.49 67.68 320.02 2,372.89 2,320.62 1,528.57 - 1,106.64 5,975,696.39 370,090.51 3.34 1,887.11 MWD +IFR -AK- CAZ -SC (2) 3,401.65 68.89 319.56 2,393.29 2,341.02 1,567.71 - 1,139.72 5,975,736.08 370,058.11 2.33 1,938.22 MWD +IFR -AK- CAZ -SC (2) 3,497.00 68.45 319.39 2,427.98 2,375.71 1,635.22 - 1,197.44 5,975,804.57 370,001.57 0.49 2,026.76 MWD +IFR -AK- CAZ -SC (2) 3,591.84 67.78 320.39 2,463.33 2,411.06 1,702.53 - 1,254.13 5,975,872.83 369,946.04 1.21 2,114.53 MWD +IFR -AK- CAZ -SC (2) 3,686.93 66.96 320.58 2,499.92 2,447.65 1,770.24 - 1,309.98 5,975,941.48 369,891.37 0.88 2,202.14 MWD +IFR -AK- CAZ -SC (2) 3,781.98 66.49 320.30 2,537.47 2,485.20 1,837.55 - 1,365.59 5,976,009.74 369,836.93 0.56 2,289.28 MWD +IFR -AK- CAZ -SC (2) 3,877.18 65.95 319.85 2,575.86 2,523.59 1,904.36 - 1,421.50 5,976,077.49 369,782.18 0.71 2,376.20 MWD +IFR -AK- CAZ -SC (2) 3,972.16 65.77 319.30 2,614.71 2,562.44 1,970.34 - 1,477.70 5,976,144.43 369,727.12 0.56 2,462.61 MWD +IFR -AK- CAZ -SC (2) 4,067.27 66.08 319.29 2,653.50 2,601.23 2,036.17 - 1,534.33 5,976,211.21 369,671.64 0.33 2,549.15 MWD +IFR -AK- CAZ -SC (2) 4,162.18 65.36 319.37 2,692.53 2,640.26 2,101.79 - 1,590.72 5,976,277.78 369,616.40 0.76 2,635.38 MWD +IFR -AK- CAZ -SC (2) 4,257.11 65.01 319.15 2,732.37 2,680.10 2,167.07 - 1,646.95 5,976,344.02 369,561.30 0.42 2,721.25 MWD +IFR -AK- CAZ -SC (2) 4,351.98 64.51 318.97 2,772.83 2,720.56 2,231.90 - 1,703.18 5,976,409.80 369,506.19 0.55 2,806.75 MWD +IFR -AK- CAZ -SC (2) 4,447.10 64.42 319.66 2,813.83 2,761.56 2,296.98 - 1,759.13 5,976,475.83 369,451.37 0.66 2,892.29 MWD +IFR -AK- CAZ -SC (2) 12/2/2009 1:04:13PM Page 3 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well CD2 -76 Project ` Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Well: CD2 - 76 North Reference: True Wellbore: CD2 - 76 Survey Calculation Method: Minimum Curvature Design: CD2 - 76 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +e-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) 0100') (ft) . Survey Tool Name 4,542.33 63.98 319.67 2,855.28 2,803.01 2,362.34 - 1,814.62 5,976,542.12 369,397.01 0.46 2,977.78 MWD +IFR -AK- CAZ -SC (2) 4,632.23 63.92 320.40 2,894.76 2,842.49 2,424.24 - 1,866.50 5,976,604.90 369,346.21 0.73 3,058.35 MWD +IFR -AK- CAZ -SC (2) 4,728.07 63.51 320.48 2,937.20 2,884.93 2,490.49 - 1,921.23 5,976,672.07 369,292.63 0.43 3,144.12 MWD +IFR -AK- CAZ -SC (2) 4,827.27 63.10 321.63 2,981.76 2,929.49 2,559.41 - 1,976.94 5,976,741.94 369,238.12 1.12 3,232.62 MWD +IFR -AK- CAZ -SC (2) 4,922.40 62.62 321.42 3,025.16 2,972.89 2,625.69 - 2,029.61 5,976,809.10 369,186.60 0.54 3,317.20 MWD +IFR -AK- CAZ -SC (2) 5,017.87 63.81 322.59 3,068.18 3,015.91 2,692.85 - 2,082.07 5,976,877.15 369,135.31 1.66 3,402.37 MWD +IFR -AK- CAZ -SC (2) 5,112.83 65.69 322.18 3,108.69 3,056.42 2,760.88 - 2,134.49 5,976,946.07 369,084.07 2.02 3,488.22 MWD +IFR -AK- CAZ -SC (2) 5,208.37 66.85 322.11 3,147.13 3,094.86 2,829.94 - 2,188.16 5,977,016.03 369,031.60 1.22 3,575.63 MWD +IFR -AK- CAZ -SC (2) 5,303.58 67.23 322.93 3,184.27 3,132.00 2,899.51 - 2,241.50 5,977,086.50 368,979.46 0.89 3,663.27 MWD +IFR -AK- CAZ -SC (2) 5,398.80 67.85 322.91 3,220.65 3,168.38 2,969.71 - 2,294.56 5,977,157.60 368,927.62 0.65 3,751.25 MWD +IFR -AK- CAZ -SC (2) 5,493.89 68.24 322.69 3,256.20 3,203.93 3,039.96 - 2,347.88 5,977,228.75 368,875.52 0.46 3,839.43 MWD +IFR -AK- CAZ -SC (2) 5,589.19 68.17 322.78 3,291.59 3,239.32 3,110.38 - 2,401.46 5,977,300.07 368,823.16 0.11 3,927.89 MWD +IFR -AK- CAZ -SC (2) 5,684.64 68.45 322.57 3,326.86 3,274.59 3,180.91 - 2,455.24 5,977,371.51 368,770.61 0.36 4,016.56 MWD +IFR -AK- CAZ -SC (2) 5,779.70 68.23 322.68 3,361.95 3,309.68 3,251.12 - 2,508.87 5,977,442.62 368,718.20 0.26 4,104.88 MWD +IFR -AK- CAZ -SC (2) 5,874.56 67.98 321.10 3,397.33 3,345.06 3,320.37 - 2,563.19 5,977,512.79 368,665.08 1.57 4,192.84 MWD +IFR -AK- CAZ -SC (2) 5,969.70 68.46 320.95 3,432.63 3,380.36 3,389.05 - 2,618.75 5,977,582.42 368,610.71 0.53 4,281.07 MWD +IFR -AK- CAZ -SC (2) 6,064.50 68.24 320.74 3,467.60 3,415.33 3,457.38 - 2,674.39 5,977,651.68 368,556.26 0.31 4,369.05 MWD +IFR -AK- CAZ -SC (2) 6,159.61 67.73 320.28 3,503.26 3,450.99 3,525.43 - 2,730.46 5,977,720.68 368,501.36 0.70 4,457.06 MWD +IFR -AK- CAZ -SC (2) 6,253.92 67.86 319.73 3,538.90 3,486.63 3,592.32 - 2,786.58 5,977,788.52 368,446.41 0.56 4,544.16 MWD +IFR -AK- CAZ -SC (2) 6,351.96 67.99 319.06 3,575.74 3,523.47 3,661.30 - 2,845.71 5,977,858.49 368,388.47 0.65 4,634.72 MWD +IFR -AK- CAZ -SC (2) 6,444.80 68.72 318.33 3,609.99 3,557.72 3,726.12 - 2,902.67 5,977,924.28 368,332.64 1.07 4,720.64 MWD +IFR -AK- CAZ -SC (2) 6,540.17 68.39 318.00 3,644.86 3,592.59 3,792.26 - 2,961.88 5,977,991.42 368,274.58 0.47 4,808.95 MWD +IFR -AK- CAZ -SC (2) 6,634.47 67.65 318.01 3,680.15 3,627.88 3,857.24 - 3,020.39 5,978,057.40 368,217.21 0.78 4,895.92 MWD +IFR -AK- CAZ -SC (2) 6,728.69 67.51 317.33 3,716.09 3,663.82 3,921.63 - 3,079.04 5,978,122.78 368,159.68 0.68 4,982.48 MWD +IFR -AK- CAZ -SC (2) 6,823.99 66.90 316.55 3,753.01 3,700.74 3,985.83 - 3,139.02 5,978,187.99 368,100.81 0.99 5,069.67 MWD +IFR -AK- CAZ -SC (2) 6,921.61 67.51 318.53 3,790.83 3,738.56 4,052.22 - 3,199.77 5,978,255.41 368,041.22 1.97 5,159.09 MWD +IFR -AK- CAZ -SC (2) 7,016.59 67.38 319.18 3,827.26 3,774.99 4,118.27 - 3,257.48 5,978,322.44 367,984.65 0.65 5,246.45 MWD +IFR -AK- CAZ -SC (2) 7,111.83 67.20 320.26 3,864.03 3,811.76 4,185.29 - 3,314.28 5,978,390.42 367,929.02 1.06 5,334.06 MWD +IFR -AK- CAZ -SC (2) 7,206.44 66.94 320.96 3,900.90 3,848.63 4,252.63 - 3,369.58 5,978,458.70 367,874.89 0.73 5,421.04 MWD +IFR -AK- CAZ -SC (2) 7,301.42 66.77 321.85 3,938.23 3,885.96 4,320.89 - 3,424.06 5,978,527.88 367,821.59 0.88 5,508.29 MWD +IFR -AK- CAZ -SC (2) 7,396.01 66.73 322.46 3,975.57 3,923.30 4,389.52 - 3,477.38 5,978,597.40 367,769.47 0.59 5,595.15 MWD +IFR -AK- CAZ -SC (2) 7,491.05 66.78 322.62 4,013.08 3,960.81 4,458.84 - 3,530.49 5,978,667.62 367,717.56 0.16 5,682.45 MWD +IFR -AK- CAZ -SC (2) 7,585.91 66.78 322.35 4,050.48 3,998.21 4,527.99 - 3,583.58 5,978,737.66 367,665.67 0.26 5,769.59 MWD +IFR -AK- CAZ -SC (2) 7,680.58 66.92 322.48 4,087.70 4,035.43 4,596.97 - 3,636.67 5,978,807.54 367,613.77 0.19 5,856.60 MWD +IFR -AK- CAZ -SC (2) 7,775.27 66.93 322.34 4,124.81 4,072.54 4,665.99 - 3,689.81 5,978,877.46 367,561.83 0.14 5,943.69 MWD +IFR -AK- CAZ -SC (2) 7,870.47 66.43 321.54 4,162.49 4,110.22 4,734.83 - 3,743.70 5,978,947.21 367,509.13 0.93 6,031.05 MWD +IFR -AK- CAZ -SC (2) 7,966.43 66.70 321.44 4,200.66 4,148.39 4,803.72 - 3,798.53 5,979,017.03 367,455.51 0.30 6,119.01 MWD +IFR -AK- CAZ -SC (2) 8,061.08 67.39 321.55 4,237.57 4,185.30 4,871.93 - 3,852.79 5,979,086.15 367,402.43 0.74 6,206.08 MWD +IFR -AK- CAZ -SC (2) 8,156.21 67.57 321.06 4,274.01 4,221.74 4,940.51 - 3,907.72 5,979,155.66 367,348.68 0.51 6,293.86 MWD +IFR -AK- CAZ -SC (2) 8,252.45 67.30 320.83 4,310.94 4,258.67 5,009.52 - 3,963.72 5,979,225.62 367,293.89 0.36 6,382.61 MWD +IFR -AK- CAZ -SC (2) 12/2/2009 1 :04 :13PM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: = Well CD2 -76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Well: CD2 -76 North Reference: True Welibore: CD2 -76 Survey Calculation Method: Minimum Curvature Design: CD2 -76 Database: CPAI EDM Production Survey Map Map Vertical - MD Inc Azi TVD TVDSS +N/-S +E/-W , Northing Easting DLS Section (ft) (°) r) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100'► (ft) Survey Tool Name 8,347.20 67.17 321.14 4,347.60 4,295.33 5,077.41 - 4,018.72 5,979,294.43 367,240.06 0.33 6,469.85 MWD +IFR -AK- CAZ -SC (2) 8,442.82 66.99 321.47 4,384.84 4,332.57 5,146.15 - 4,073.78 5,979,364.10 367,186.20 0.37 6,557.83 MWD +IFR -AK- CAZ -SC (2) 8,537.82 67.25 321.00 4,421.78 4,369.51 5,214.39 - 4,128.58 5,979,433.27 367,132.58 0.53 6,645.25 MWD +IFR -AK- CAZ -SC (2) 8,633.23 66.80 321.34 4,459.02 4,406.75 5,282.82 - 4,183.66 5,979,502.63 367,078.69 0.57 6,732.98 MWD +IFR -AK- CAZ -SC (2) 8,728.34 66.71 320.97 4,496.56 4,444.29 5,350.88 - 4,238.47 5,979,571.62 367,025.06 0.37 6,820.27 MWD +IFR -AK- CAZ -SC (2) 8,823.94 66.92 320.81 4,534.19 4,481.92 5,419.07 - 4,293.91 5,979,640.75 366,970.81 0.27 6,908.02 MWD +IFR -AK- CAZ -SC (2) 8,919.04 67.18 320.90 4,571.28 4,519.01 5,486.99 - 4,349.19 5,979,709.60 366,916.71 0.29 6,995.46 MWD +IFR -AK- CAZ -SC (2) 9,014.08 66.80 321.37 4,608.43 4,556.16 5,555.10 - 4,404.08 5,979,778.64 366,863.00 0.61 7,082.82 MWD +IFR -AK- CAZ -SC (2) 9,109.18 66.71 321.70 4,645.96 4,593.69 5,623.52 - 4,458.43 5,979,847.97 366,809.83 0.33 7,170.12 MWD +IFR -AK- CAZ -SC (2) 9,204.60 66.78 321.26 4,683.63 4,631.36 5,692.11 - 4,513.03 5,979,917.48 366,756.42 0.43 7,257.71 MWD +IFR -AK- CAZ -SC (2) 9,299.69 66.84 321.22 4,721.08 4,668.81 5,760.27 - 4,567.75 5,979,986.57 366,702.89 0.07 7,345.01 MWD +IFR -AK- CAZ -SC (2) 9,394.95 66.43 321.70 4,758.86 4,706.59 5,828.66 - 4,622.24 5,980,055.89 366,649.59 0.63 7,432.37 MWD +IFR -AK- CAZ -SC (2) 9,488.83 66.44 321.78 4,796.39 4,744.12 5,896.23 - 4,675.53 5,980,124.35 366,597.47 0.08 7,518.36 MWD +IFR -AK- CAZ -SC (2) 9,584.77 66.30 321.55 4,834.84 4,782.57 5,965.18 - 4,730.04 5,980,194.22 366,544.15 0.26 7,606.18 MWD +IFR -AK- CAZ -SC (2) 9,679.73 66.84 320.92 4,872.60 4,820.33 6,033.11 - 4,784.60 5,980,263.08 366,490.78 0.83 7,693.21 MWD +IFR -AK- CAZ -SC (2) 9,774.87 66.86 321.64 4,910.01 4,857.74 6,101.37 - 4,839.32 5,980,332.25 366,437.24 0.70 7,780.59 MWD +IFR -AK- CAZ -SC (2) 9,870.10 66.58 321.67 4,947.64 4,895.37 6,169.97 - 4,893.59 5,980,401.78 366,384.17 0.30 7,867.99 MWD +IFR -AK- CAZ -SC (2) 9,965.79 66.45 321.50 4,985.78 4,933.51 6,238.74 - 4,948.12 5,980,471.46 366,330.83 0.21 7,955.68 MWD +IFR -AK- CAZ -SC (2) 10,060.34 66.44 321.69 5,023.56 4,971.29 6,306.66 - 5,001.96 5,980,540.29 366,278.16 0.18 8,042.27 MWD +IFR -AK- CAZ -SC (2) 10,155.69 66.29 321.31 5,061.79 5,009.52 6,375.02 - 5,056.34 5,980,609.57 366,224.97 0.40 8,129.54 MWD +IFR -AK- CAZ -SC (2) 10,250.19 66.81 321.45 5,099.40 5,047.13 6,442.75 - 5,110.45 5,980,678.22 366,172.04 0.57 8,216.15 MWD +IFR -AK- CAZ -SC (2) 10,345.49 66.78 321.15 5,136.95 5,084.68 6,511.11 - 5,165.22 5,980,747.51 366,118.46 0.29 8,303.64 MWD +IFR -AK- CAZ -SC (2) 10,440.89 66.92 321.39 5,174.45 5,122.18 6,579.54 - 5,220.10 5,980,816.86 366,064.77 0.27 8,391.26 MWD +IFR -AK- CAZ -SC (2) 10,536.02 66.63 320.67 5,211.97 5,159.70 6,647.51 - 5,275.08 5,980,885.76 366,010.97 0.76 8,478.56 MWD +IFR -AK- CAZ -SC (2) 10,630.50 66.52 320.35 5,249.53 5,197.26 6,714.41 - 5,330.21 5,980,953.59 365,957.00 0.33 8,565.09 MWD +IFR -AK- CAZ -SC (2) 10,725.59 66.77 320.32 5,287.22 5,234.95 6,781.61 - 5,385.93 5,981,021.74 365,902.44 0.26 8,652.21 MWD +IFR -AK- CAZ -SC (2) 10,820.31 66.98 320.28 5,324.42 5,272.15 6,848.64 - 5,441.57 5,981,089.70 365,847.97 0.23 8,739.14 MWD +IFR -AK- CAZ -SC (2) 10,915.64 66.78 320.12 5,361.85 5,309.58 6,915.99 - 5,497.69 5,981,158.01 365,793.01 0.26 8,826.62 MWD +IFR -AK- CAZ -SC (2) 11,009.97 66.66 320.23 5,399.14 5,346.87 6,982.54 - 5,553.19 5,981,225.49 365,738.68 0.17 8,913.08 MWD +IFR -AK- CAZ -SC (2) 11,105.36 66.45 319.99 5,437.09 5,384.82 7,049.69 - 5,609.31 5,981,293.59 365,683.72 0.32 9,000.39 MWD +IFR -AK- CAZ -SC (2) 11,200.68 66.64 319.99 5,475.03 5,422.76 7,116.67 - 5,665.53 5,981,361.52 365,628.66 0.20 9,087.62 MWD +IFR -AK- CAZ -SC (2) 11,296.29 66.98 320.51 5,512.68 5,460.41 7,184.24 - 5,721.73 5,981,430.04 365,573.64 0.61 9,175.32 MWD +IFR -AK- CAZ -SC (2) 11,391.31 67.03 320.83 5,549.80 5,497.53 7,251.89 - 5,777.16 5,981,498.63 365,519.38 0.31 9,262.64 MWD +IFR -AK- CAZ -SC (2) 11,486.42 66.86 321.92 5,587.05 5,534.78 7,320.26 - 5,831.79 5,981,567.92 365,465.94 1.07 9,350.06 MWD +IFR -AK- CAZ -SC (2) 11,581.56 67.13 322.39 5,624.23 5,571.96 7,389.42 - 5,885.52 5,981,637.98 365,413.41 0.54 9,437.59 MWD +IFR -AK- CAZ -SC (2) 11,676.96 66.17 322.07 5,662.04 5,609.77 7,458.65 - 5,939.17 5,981,708.12 365,360.97 1.05 9,525.13 MWD +IFR -AK- CAZ -SC (2) 11,772.23 65.97 321.58 5,700.68 5,648.41 7,527.11 - 5,992.99 5,981,777.49 365,308.33 0.51 9,612.15 MWD +IFR -AK- CAZ -SC (2) 11,867.73 65.99 321.87 5,739.56 5,687.29 7,595.59 - 6,047.02 5,981,846.88 365,255.49 0.28 9,699.31 MWD +IFR -AK- CAZ -SC (2) 11,963.17 66.25 321.50 5,778.19 5,725.92 7,664.06 - 6,101.13 5,981,916.27 365,202.57 0.45 9,786.51 MWD +IFR -AK- CAZ -SC (2) 12,058.61 66.46 320.81 5,816.47 5,764.20 7,732.15 - 6,155.96 5,981,985.29 365,148.92 0.70 9,873.83 MWD +IFR -AK- CAZ -SC (2) 12/2/2009 1:04:13PM Page 5 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well CD2 -76 Project: Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: '. CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Well: CD2 - 76 North Reference: True Wellbore: CD2 - 76 Survey Calculation Method: Minimum Curvature Design: CD2 - 76 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS ` Section (ft) ( °) (°) (ft) (ft) (ft) (ft) (ft) (ft) ( °/100') (ft) Survey Tool Name 12,151.70 67.24 321.03 5,853.07 5,800.80 7,798.60 - 6,209.92 5,982,052.64 365,096.11 0.87 9,959.30 MWD +IFR -AK- CAZ -SC (2) 12,245.61 67.65 321.04 5,889.09 5,836.82 7,866.03 - 6,264.46 5,982,121.00 365,042.75 0.44 10,045.91 MWD +IFR -AK- CAZ -SC (2) 12,337.08 67.12 320.98 5,924.26 5,871.99 7,931.66 - 6,317.58 5,982,187.52 364,990.76 0.58 10,130.23 MWD +IFR -AK- CAZ -SC (2) 12,431.63 66.65 320.75 5,961.38 5,909.11 7,999.11 - 6,372.47 5,982,255.90 364,937.05 0.55 10,217.06 MWD +IFR -AK- CAZ -SC (2) 12,523.16 66.85 320.13 5,997.51 5,945.24 8,063.94 - 6,426.03 5,982,321.64 364,884.61 0.66 10,300.99 MWD +IFR -AK- CAZ -SC (2) 12,615.32 67.12 320.07 6,033.54 5,981.27 8,129.02 - 6,480.44 5,982,387.64 364,831.33 0.30 10,385.62 MWD +IFR -AK- CAZ -SC (2) 12,675.00 67.56 320.09 6,056.54 6,004.27 8,171.25 - 6,515.78 5,982,430.47 364,796.73 0.73 10,440.56 MWD +IFR -AK- CAZ -SC (2) 12,734.20 69.94 317.17 6,078.00 6,025.73 8,212.64 - 6,552.25 5,982,472.48 364,760.98 6.11 10,495.48 MWD +IFR -AK- CAZ -SC (3) 12,828.16 69.00 312.57 6,110.96 6,058.69 8,274.71 - 6,614.58 5,982,535.60 364,699.73 4.69 10,582.33 MWD +IFR -AK- CAZ -SC (3) 12,880.38 68.87 310.03 6,129.74 6,077.47 8,306.87 - 6,651.18 5,982,568.38 364,663.68 4.55 10,629.87 MWD +IFR -AK- CAZ -SC (3) 12,924.73 67.32 311.99 6,146.28 6,094.01 8,333.86 - 6,682.23 5,982,595.90 364,633.10 5.39 10,669.96 MWD +IFR -AK- CAZ -SC (3) 12,973.97 67.14 311.89 6,165.34 6,113.07 8,364.21 - 6,716.01 5,982,626.82 364,599.86 0.41 10,714.36 MWD +IFR -AK- CAZ -SC (3) 13,019.85 66.83 311.99 6,183.28 6,131.01 8,392.43 - 6,747.42 5,982,655.58 364,568.94 0.70 10,755.65 MWD +IFR -AK- CAZ -SC (3) 13,115.11 66.67 312.05 6,220.88 6,168.61 8,451.02 - 6,812.44 5,982,715.27 364,504.94 0.18 10,841.27 MWD +IFR -AK- CAZ -SC (3) 13,210.48 66.70 311.56 6,258.63 6,206.36 8,509.40 - 6,877.72 5,982,774.76 364,440.67 0.47 10,926.88 MWD +IFR -AK- CAZ -SC (3) 13,305.19 66.84 312.07 6,295.98 6,243.71 8,567.43 - 6,942.59 5,982,833.88 364,376.82 0.52 11,011.95 MWD +IFR -AK- CAZ -SC (3) 13,401.43 65.64 313.00 6,334.76 6,282.49 8,626.97 - 7,007.49 5,982,894.53 364,312.95 1.53 11,098.27 MWD +IFR -AK- CAZ -SC (3) 13,418.35 65.41 312.92 6,341.77 6,289.50 8,637.47 - 7,018.76 5,982,905.22 364,301.86 1.43 11,113.38 MWD +IFR -AK- CAZ -SC (3) 13,470.44 65.02 312.25 6,363.61 6,311.34 8,669.47 - 7,053.58 5,982,937.81 364,267.60 1.39 11,159.74 MWD +IFR -AK- CAZ -SC (3) 13,566.47 65.02 314.94 6,404.17 6,351.90 8,729.48 - 7,116.62 5,982,998.89 364,205.61 2.54 11,245.34 MWD +IFR -AK- CAZ -SC (3) 13,661.64 66.72 319.06 6,443.08 6,390.81 8,793.00 - 7,175.82 5,983,063.41 364,147.52 4.34 11,331.52 MWD +IFR -AK- CAZ -SC (3) 13,756.17 66.91 321.03 6,480.30 6,428.03 8,859.60 - 7,231.62 5,983,130.96 364,092.88 1.93 11,418.21 MWD +IFR -AK- CAZ -SC (3) 13,851.87 67.18 321.50 6,517.63 6,465.36 8,928.34 - 7,286.75 5,983,200.63 364,038.93 0.53 11,506.23 MWD +IFR -AK- CAZ -SC (3) 13,947.30 66.31 321.56 6,555.31 6,503.04 8,996.99 - 7,341.30 5,983,270.20 363,985.58 0.91 11,593.82 MWD +IFR -AK- CAZ -SC (3) 14,043.33 67.03 325.39 6,593.35 6,541.08 9,067.84 - 7,393.76 5,983,341.93 363,934.35 3.74 11,681.98 MWD +IFR -AK- CAZ -SC (3) 14,138.54 66.71 327.27 6,630.75 6,578.48 9,140.70 - 7,442.30 5,983,415.61 363,887.07 1.85 11,769.46 MWD +IFR -AK- CAZ -SC (3) 14,233.65 65.63 327.04 6,669.18 6,616.91 9,213.79 - 7,489.49 5,983,489.49 363,841.15 1.16 11,856.32 MWD +IFR -AK- CAZ -SC (3) 14,328.89 66.18 326.57 6,708.06 6,655.79 9,286.54 - 7,537.09 5,983,563.05 363,794.81 0.73 11,943.16 MWD +IFR -AK- CAZ -SC (3) 14,424.87 65.83 327.07 6,747.09 6,694.82 9,359.93 - 7,585.07 5,983,637.24 363,748.09 0.60 12,030.74 MWD +IFR -AK- CAZ -SC (3) 14,519.75 66.37 326.69 6,785.53 6,733.26 9,432.58 - 7,632.47 5,983,710.69 363,701.96 0.68 12,117.37 MWD +IFR -AK- CAZ -SC (3) 14,613.86 65.63 326.11 6,823.81 6,771.54 9,504.19 - 7,680.05 5,983,783.10 363,655.62 0.97 12,203.27 MWD +IFR -AK- CAZ -SC (3) 14,710.47 66.10 323.49 6,863.32 6,811.05 9,576.22 - 7,730.87 5,983,855.99 363,606.05 2.52 12,291.42 MWD +IFR -AK- CAZ -SC (3) 14,806.05 65.34 321.72 6,902.62 6,850.35 9,645.44 - 7,783.77 5,983,926.10 363,554.35 1.87 12,378.51 MWD +IFR -AK- CAZ -SC (3) 14,901.65 65.67 321.60 6,942.26 6,889.99 9,713.68 - 7,837.74 5,983,995.25 363,501.57 0.36 12,465.43 MWD +IFR -AK- CAZ -SC (3) 14,997.04 65.95 322.57 6,981.35 6,929.08 9,782.32 - 7,891.20 5,984,064.80 363,449.29 0.97 12,552.40 MWD +IFR -AK- CAZ -SC (3) 15,092.30 66.62 323.32 7,019.66 6,967.39 9,851.93 - 7,943.76 5,984,135.29 363,397.95 1.01 12,639.60 MWD +IFR -AK- CAZ -SC (3) 15,188.26 66.35 323.43 7,057.95 7,005.68 9,922.54 - 7,996.25 5,984,206.79 363,346.68 0.30 12,727.58 MWD +IFR -AK- CAZ -SC (3) 15,283.39 66.63 323.35 7,095.89 7,043.62 9,992.57 - 8,048.27 5,984,277.69 363,295.87 0.30 12,814.81 MWD +IFR -AK- CAZ -SC (3) 15,378.58 66.82 322.79 7,133.51 7,081.24 10,062.47 - 8,100.81 5,984,348.48 363,244.54 0.58 12,902.24 MWD +IFR -AK- CAZ -SC (3) 15,473.93 65.97 320.69 7,171.69 7,119.42 10,131.07 - 8,154.91 5,984,417.99 363,191.64 2.21 12,989.54 MWD +IFR -AK- CAZ -SC (3) 12/2/2009 1:04:13PM Page 6 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well CD2 -76 Project Western North Slope TVD Reference: ! = CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Well: CD2 - 76 North Reference: True Wellbore: ! CD2 - 76 Survey Calculation Method: Minimum Curvature Design: CD2 - 76 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD : TVDSS +NI-S +E!-W Northing Easting DLS Section (ft) r) (°) (ft) (ft) (ft) (ft) (ft) (ft) (*moo (ft) Survey Tool Name 15,569.58 65.36 320.14 7,211.11 7,158.84 10,198.23 - 8,210.44 5,984,486.10 363,137.27 0.83 13,076.52 MWD +IFR- AK- CAZ -SC (3) 15,664.87 63.70 319.79 7,252.08 7,199.81 10,264.10 - 8,265.78 5,984,552.90 363,083.08 1.77 13,162.33 MWD +IFR- AK- CAZ -SC (3) 15,703.20 63.64 320.07 7,269.08 7,216.81 10,290.39 - 8,287.89 5,984,579.56 363,061.42 0.67 13,196.60 MWD +IFR- AK- CAZ -SC (3) 15,769.00 63.64 320.07 7,298.30 7,246.03 10,335.60 - 8,325.73 5,984,625.41 363,024.37 0.00 13,255.42 PROJECTED to TD 12/2/2009 1:04:13PM Page 7 COMPASS 2003.16 Build 69 0 • l i s ConocoPhilli Alaska K ConocoPhillips(Alaska) Inc. i Western North Slope CD2 Alpine Pad I CD2 -76PB1 501032060370 3 1 . .jK i . r Definitive Survey Report 23 November, 2009 t 4 mm q Y 4 ■ i : i j } t i HALLIBURTON l "aril - i Sperry Drilling Services • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well Rig: CD2 -76 Project Western North Slope ND Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Well: Rig: CD2 - 76 North Reference: True Wel!bore: CD2 - 76PB1 Survey Calculation Method: Minimum Curvature Design: CD2 -76PB1 Database: CPAI EDM Production Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Rig: CD2 -76 Well Position +N / -S 0.00 ft Northing: 5,974,149.15ft Latitude: 70° 20' 15.293 N +E/ -W 0.00 ft Easting: 371,170.64 ft Longitude: 151° 2' 43.187 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 15.60ft Wellbore CD2 - 76PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Streng ( ( (nT) BGGM2007 10/10/2009 21.32 80.70 57,619 Design CD2 - 76PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.67 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) (0) 36.67 0.00 0.00 324.00 Survey Program Date From To (ft) (ft), Survey (Wellbore) Tool Name Description Survey Date 100.00 633.00 CD2- 176PB1 (gyro) (CD2- 76PB1) CB- GYRO -SS Camera based gyro single shot 10/19/2009 • 672.70 16,517.57 CD2- 176PB1 (mwd) (CD2- 76PB1) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 10/20/2009 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) ( ( (ft) (ft) ;, (ft) (ft) (ft) (ft) (0/1®) (ft) Survey Tool Name 36.67 0.00 0.00 36.67 -15.60 0.00 0.00 5,974,149.15 371,170.64 0.00 0.00 UNDEFINED 100.00 0.40 142.57 100.00 47.73 -0.18 0.13 5,974,148.97 371,170.77 0.63 -0.22 CB- GYRO -SS (1) 142.00 0.48 127.28 142.00 89.73 -0.40 0.36 5,974,148.75 371,171.00 0.34 -0.54 CB- GYRO -SS (1) 172.00 0.53 141.35 172.00 119.73 -0.58 0.55 5,974,148.56 371,171.18 0.44 -0.79 CB- GYRO -SS (1) 263.00 1.23 351.93 262.99 210.72 0.06 0.68 5,974,149.19 371,171.32 1.88 -0.35 CB- GYRO -SS (1) 356.00 3.73 348.51 355.90 303.63 4.01 -0.07 5,974,153.16 371,170.64 2.69 3.28 CB- GYRO -SS (1) 448.00 6.34 344.69 447.53 395.26 11.84 -2.00 5,974,161.02 371,168.84 2.86 10.76 CB- GYRO -SS (1) 541.00 8.39 341.46 539.76 487.49 23.23 -5.52 5,974,172.47 371,165.52 2.25 22.04 CB- GYRO -SS (1) 633.00 10.13 340.65 630.56 578.29 37.23 -10.33 5,974,186.55 371,160.95 1.90 36.19 CB- GYRO -SS (1) 672.70 11.19 344.87 669.58 617.31 44.24 -12.50 5,974,193.59 371,158.91 3.31 43.14 MWD +IFR -AK- CAZ -SC (2) 764.13 14.03 342.25 758.79 706.52 63.36 -18.19 5,974,212.81 371,153.54 3.17 61.95 MWD +IFR -AK- CAZ -SC (2) 856.86 15.46 342.54 848.47 796.20 85.86 -25.33 5,974,235.42 371,146.79 1.54 84.35 MWD +IFR -AK- CAZ -SC (2) 952.27 17.77 341.11 939.89 887.62 111.77 -33.86 5,974,261.47 371,138.71 2.46 110.32 MWD +IFR -AK- CAZ -SC (2) 11/23/2009 12 :53 :41 PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well Rig: CD2 -76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft ( Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Well: Rig: CD2 -76 North Reference: True Wellbore: CD2 -76PB1 Survey Calculation Method: Minimum Curvature Design: CD2 -76PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +Ni-S +E! -W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) ( °!100) . (ft) Survey Tool Name 1,047.22 21.41 343.11 1,029.33 977.06 142.07 -43.59 5,974,291.94 371,129.50 3.90 140.56 MWD +IFR -AK- CAZ -SC (2) 1,140.29 22.96 341.32 1,115.50 1,063.23 175.52 -54.34 5,974,325.57 371,119.33 1.82 173.94 MWD +IFR -AK- CAZ -SC (2) 1,237.76 24.38 335.73 1,204.78 1,152.51 211.88 -68.70 5,974,362.16 371,105.60 2.72 211.79 MWD +IFR -AK- CAZ -SC (2) 1,331.96 27.18 330.97 1,289.61 1,237.34 248.43 -87.13 5,974,399.02 371,087.79 3.69 252.20 MWD +IFR -AK- CAZ -SC (2) 1,427.39 32.40 326.99 1,372.41 1,320.14 288.96 - 111.66 5,974,439.96 371,063.97 5.85 299.40 MWD +IFR -AK- CAZ -SC (2) 1,479.91 34.24 325.94 1,416.29 1,364.02 313.00 - 127.60 5,974,464.27 371,048.45 3.67 328.22 MWD +IFR -AK- CAZ -SC (2) 1,523.20 35.37 325.93 1,451.84 1,399.57 333.47 - 141.44 5,974,484.97 371,034.96 2.61 352.92 MWD +IFR -AK- CAZ -SC (2) 1,617.86 38.28 324.49 1,527.60 1,475.33 380.04 - 173.83 5,974,532.09 371,003.38 3.21 409.63 MWD +IFR -AK- CAZ -SC (2) 1,712.90 40.56 324.16 1,601.02 1,548.75 429.06 - 209.02 5,974,581.70 370,969.03 2.41 469.98 MWD +IFR -AK- CAZ -SC (2) 1,808.35 43.69 325.59 1,671.80 1,619.53 481.43 - 245.83 5,974,634.69 370,933.13 3.43 533.98 MWD +IFR -AK- CAZ -SC (2) 1,902.26 47.49 323.99 1,737.51 1,685.24 536.21 - 284.53 5,974,690.12 370,895.39 4.23 601.04 MWD +IFR -AK- CAZ -SC (2) 1,998.67 51.67 321.90 1,800.01 1,747.74 594.74 - 328.78 5,974,749.40 370,852.16 4.64 674.40 MWD +IFR -AK- CAZ -SC (2) 2,093.17 55.51 320.64 1,856.09 1,803.82 654.04 - 376.36 5,974,809.51 370,805.60 4.20 750.35 MWD +IFR -AK- CAZ -SC (2) 2,189.59 58.05 320.91 1,908.91 1,856.64 716.53 - 427.37 5,974,872.85 370,755.68 2.64 830.88 MWD +IFR -AK- CAZ -SC (2) 2,284.69 61.64 321.42 1,956.68 1,904.41 780.57 - 478.92 5,974,937.77 370,705.24 3.80 913.00 MWD +IFR -AK- CAZ -SC (2) 2,378.58 65.62 320.38 1,998.37 1,946.10 845.83 - 531.97 5,975,003.93 370,653.32 4.35 996.98 MWD +IFR -AK- CAZ -SC (2) 2,475.53 67.74 320.43 2,036.75 1,984.48 914.43 - 588.71 5,975,073.49 370,597.78 2.19 1,085.83 MWD +IFR -AK- CAZ -SC (2) 2,570.79 65.88 320.35 2,074.26 2,021.99 981.89 - 644.53 5,975,141.89 370,543.12 1.95 1,173.21 MWD +IFR -AK- CAZ -SC (2) 2,666.31 65.73 319.91 2,113.41 2,061.14 1,048.76 - 700.39 5,975,209.70 370,488.43 0.45 1,260.14 MWD +IFR -AK- CAZ -SC (2) 2,761.50 67.51 320.11 2,151.18 2,098.91 1,115.70 - 756.53 5,975,277.59 370,433.45 1.88 1,347.30 MWD +IFR -AK- CAZ -SC (2) 2,856.69 67.56 319.95 2,187.56 2,135.29 1,183.12 - 813.04 5,975,345.96 370,378.11 0.16 1,435.06 MWD +IFR -AK- CAZ -SC (2) 2,951.75 68.29 320.43 2,223.28 2,171.01 1,250.78 - 869.44 5,975,414.58 370,322.88 0.90 1,522.95 MWD +IFR -AK- CAZ -SC (2) 3,047.09 67.89 319.32 2,258.86 2,206.59 1,318.42 - 926.44 5,975,483.18 370,267.06 1.16 1,611.17 MWD +IFR -AK- CAZ -SC (2) 3,141.95 67.54 318.90 2,294.83 2,242.56 1,384.77 - 983.90 5,975,550.51 370,210.75 0.55 1,698.63 MWD +IFR -AK- CAZ -SC (2) 3,237.72 67.65 319.74 2,331.33 2,279.06 1,451.92 - 1,041.61 5,975,618.63 370,154.21 0.82 1,786.87 MWD +IFR -AK- CAZ -SC (2) 3,332.90 67.43 319.61 2,367.70 2,315.43 1,518.98 - 1,098.54 5,975,686.65 370,098.45 0.26 1,874.58 MWD +IFR -AK- CAZ -SC (2) 3,346.49 67.68 320.02 2,372.89 2,320.62 1,528.57 - 1,106.64 5,975,696.39 370,090.51 3.34 1,887.11 MWD +IFR -AK- CAZ -SC (2) 3,401.65 68.89 319.56 2,393.29 2,341.02 1,567.71 - 1,139.72 5,975,736.08 370,058.11 2.33 1,938.22 MWD +IFR -AK- CAZ -SC (2) 3,497.00 68.45 319.39 2,427.98 2,375.71 1,635.22 - 1,197.44 5,975,804.57 370,001.57 0.49 2,026.76 MWD +IFR -AK- CAZ -SC (2) 3,591.84 67.78 320.39 2,463.33 2,411.06 1,702.53 - 1,254.13 5,975,872.83 369,946.04 1.21 2,114.53 MWD +IFR -AK- CAZ -SC (2) 3,686.93 66.96 320.58 2,499.92 2,447.65 1,770.24 - 1,309.98 5,975,941.48 369,891.37 0.88 2,202.14 MWD +IFR -AK- CAZ -SC (2) 3,781.98 66.49 320.30 2,537.47 2,485.20 1,837.55 - 1,365.59 5,976,009.74 369,836.93 0.56 2,289.28 MWD +IFR -AK- CAZ -SC (2) 3,877.18 65.95 319.85 2,575.86 2,523.59 1,904.36 - 1,421.50 5,976,077.49 369,782.18 0.71 2,376.20 MWD +IFR -AK- CAZ -SC (2) 3,972.16 65.77 319.30 2,614.71 2,562.44 1,970.34 - 1,477.70 5,976,144.43 369,727.12 0.56 2,462.61 MWD +IFR -AK- CAZ -SC (2) 4,067.27 66.08 319.29 2,653.50 2,601.23 2,036.17 - 1,534.33 5,976,211.21 369,671.64 0.33 2,549.15 MWD +IFR -AK- CAZ -SC (2) 4,162.18 65.36 319.37 2,692.53 2,640.26 2,101.79 - 1,590.72 5,976,277.78 369,616.40 0.76 2,635.38 MWD +IFR -AK- CAZ -SC (2) 4,257.11 65.01 319.15 2,732.37 2,680.10 2,167.07 - 1,646.95 5,976,344.02 369,561.30 0.42 2,721.25 MWD +IFR -AK- CAZ -SC (2) 4,351.98 64.51 318.97 2,772.83 2,720.56 2,231.90 - 1,703.18 5,976,409.80 369,506.19 0.55 2,806.75 MWD +IFR -AK- CAZ -SC (2) 4,447.10 64.42 319.66 2,813.83 2,761.56 2,296.98 - 1,759.13 5,976,475.83 369,451.37 0.66 2,892.29 MWD +IFR -AK- CAZ -SC (2) 4,542.33 63.98 319.67 2,855.28 2,803.01 2,362.34 - 1,814.62 5,976,542.12 369,397.01 0.46 2,977.78 MWD +IFR -AK- CAZ -SC (2) 11/23/2009 12:53 :41 PM Page 3 COMPASS 2003.16 Build 69 • ConocoPhillips Definitive Survey Report Company: ' ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well Rig: CD2 -76 Project Western North Slope TVD Reference: - CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: ! CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Well: Rig: CD2 - 76 North Reference: True Welibore: CD2 -76PB1 Survey Calculation Method: Minimum Curvature Design :. CD2 -76PB1 Database: CPAI EDM Production Survey Map Map Vertical : MD Inc Az! TVD TVDSS +N►.S +EI-W Northing Easting DLS Section (ft) C) ( °) (ft) (ft) (ft) (ft) (ft) (ft) (%1o0') (ft) Survey Tool Name 4,632.23 63.92 320.40 2,894.76 2,842.49 2,424.24 - 1,866.50 5,976,604.90 369,346.21 0.73 3,058.35 MWD +IFR -AK- CAZ -SC (2) 4,728.07 63.51 320.48 2,937.20 2,884.93 2,490.49 - 1,921.23 5,976,672.07 369,292.63 0.43 3,144.12 MWD +IFR -AK- CAZ -SC (2) 4,827.27 63.10 321.63 2,981.76 2,929.49 2,559.41 - 1,976.94 5,976,741.94 369,238.12 1.12 3,232.62 MWD +IFR -AK- CAZ -SC (2) 4,922.40 62.62 321.42 3,025.16 2,972.89 2,625.69 - 2,029.61 5,976,809.10 369,186.60 0.54 3,317.20 MWD +IFR -AK- CAZ -SC (2) 5,017.87 63.81 322.59 3,068.18 3,015.91 2,692.85 - 2,082.07 5,976,877.15 369,135.31 1.66 3,402.37 MWD +IFR -AK- CAZ -SC (2) 5,112.83 65.69 322.18 3,108.69 3,056.42 2,760.88 - 2,134.49 5,976,946.07 369,084.07 2.02 3,488.22 MWD +IFR -AK- CAZ -SC (2) 5,208.37 66.85 322.11 3,147.13 3,094.86 2,829.94 - 2,188.16 5,977,016.03 369,031.60 1.22 3,575.63 MWD +IFR -AK- CAZ -SC (2) 5,303.58 67.23 322.93 3,184.27 3,132.00 2,899.51 - 2,241.50 5,977,086.50 368,979.46 0.89 3,663.27 MWD +IFR -AK- CAZ -SC (2) 5,398.80 67.85 322.91 3,220.65 3,168.38 2,969.71 - 2,294.56 5,977,157.60 368,927.62 0.65 3,751.25 MWD +IFR -AK- CAZ -SC (2) 5,493.89 68.24 322.69 3,256.20 3,203.93 3,039.96 - 2,347.88 5,977,228.75 368,875.52 0.46 3,839.43 MWD +IFR -AK- CAZ -SC (2) 5,589.19 68.17 322.78 3,291.59 3,239.32 3,110.38 - 2,401.46 5,977,300.07 368,823.16 0.11 3,927.89 MWD +IFR -AK- CAZ -SC (2) 5,684.64 68.45 322.57 3,326.86 3,274.59 3,180.91 - 2,455.24 5,977,371.51 368,770.61 0.36 4,016.56 MWD +IFR -AK- CAZ -SC (2) 5,779.70 68.23 322.68 3,361.95 3,309.68 3,251.12 - 2,508.87 5,977,442.62 368,718.20 0.26 4,104.88 MWD +IFR -AK- CAZ -SC (2) 5,874.56 67.98 321.10 3,397.33 3,345.06 3,320.37 - 2,563.19 5,977,512.79 368,665.08 1.57 4,192.84 MWD +IFR -AK- CAZ -SC (2) 5,969.70 68.46 320.95 3,432.63 3,380.36 3,389.05 - 2,618.75 5,977,582.42 368,610.71 0.53 4,281.07 MWD +IFR -AK- CAZ -SC (2) 6,064.50 68.24 320.74 3,467.60 3,415.33 3,457.38 - 2,674.39 5,977,651.68 368,556.26 0.31 4,369.05 MWD +IFR -AK- CAZ -SC (2) 6,159.61 67.73 320.28 3,503.26 3,450.99 3,525.43 - 2,730.46 5,977,720.68 368,501.36 0.70 4,457.06 MWD +IFR -AK- CAZ -SC (2) 6,253.92 67.86 319.73 3,538.90 3,486.63 3,592.32 - 2,786.58 5,977,788.52 368,446.41 0.56 4,544.16 MWD +IFR -AK- CAZ -SC (2) 6,351.96 67.99 319.06 3,575.74 3,523.47 3,661.30 - 2,845.71 5,977,858.49 368,388.47 0.65 4,634.72 MWD +IFR -AK- CAZ -SC (2) 6,444.80 68.72 318.33 3,609.99 3,557.72 3,726.12 - 2,902.67 5,977,924.28 368,332.64 1.07 4,720.64 MWD +IFR -AK- CAZ -SC (2) 6,540.17 68.39 318.00 3,644.86 3,592.59 3,792.26 - 2,961.88 5,977,991.42 368,274.58 0.47 4,808.95 MWD +IFR -AK- CAZ -SC (2) 6,634.47 67.65 318.01 3,680.15 3,627.88 3,857.24 - 3,020.39 5,978,057.40 368,217.21 0.78 4,895.92 MWD +IFR -AK- CAZ -SC (2) 6,728.69 67.51 317.33 3,716.09 3,663.82 3,921.63 - 3,079.04 5,978,122.78 368,159.68 0.68 4,982.48 MWD +IFR -AK- CAZ -SC (2) 6,823.99 66.90 316.55 3,753.01 3,700.74 3,985.83 - 3,139.02 5,978,187.99 368,100.81 0.99 5,069.67 MWD +IFR -AK- CAZ -SC (2) 6,921.61 67.51 318.53 3,790.83 3,738.56 4,052.22 - 3,199.77 5,978,255.41 368,041.22 1.97 5,159.09 MWD +IFR -AK- CAZ -SC (2) 7,016.59 67.38 319.18 3,827.26 3,774.99 4,118.27 - 3,257.48 5,978,322.44 367,984.65 0.65 5,246.45 MWD +IFR -AK- CAZ -SC (2) 7,111.83 67.20 320.26 3,864.03 3,811.76 4,185.29 - 3,314.28 5,978,390.42 367,929.02 1.06 5,334.06 MWD +IFR -AK- CAZ -SC (2) 7,206.44 66.94 320.96 3,900.90 3,848.63 4,252.63 - 3,369.58 5,978,458.70 367,874.89 0.73 5,421.04 MWD +IFR -AK- CAZ -SC (2) 7,301.42 66.77 321.85 3,938.23 3,885.96 4,320.89 - 3,424.06 5,978,527.88 367,821.59 0.88 5,508.29 MWD +IFR -AK- CAZ -SC (2) 7,396.01 66.73 322.46 3,975.57 3,923.30 4,389.52 - 3,477.38 5,978,597.40 367,769.47 0.59 5,595.15 MWD +IFR -AK- CAZ -SC (2) 7,491.05 66.78 322.62 4,013.08 3,960.81 4,458.84 - 3,530.49 5,978,667.62 367,717.56 0.16 5,682.45 MWD +IFR -AK- CAZ -SC (2) 7,585.91 66.78 322.35 4,050.48. 3,998.21 4,527.99 - 3,583.58 5,978,737.66 367,665.67 0.26 5,769.59 MWD +IFR -AK- CAZ -SC (2) 7,680.58 66.92 322.48 4,087.70 4,035.43 4,596.97 - 3,636.67 5,978,807.54 367,613.77 0.19 5,856.60 MWD +IFR -AK- CAZ -SC (2) 7,775.27 66.93 322.34 4,124.81 4,072.54 4,665.99 - 3,689.81 5,978,877.46 367,561.83 0.14 5,943.69 MWD +IFR -AK- CAZ -SC (2) 7,870.47 66.43 321.54 4,162.49 4,110.22 4,734.83 - 3,743.70 5,978,947.21 367,509.13 0.93 6,031.05 MWD +IFR -AK- CAZ -SC (2) 7,966.43 66.70 321.44 4,200.66 4,148.39 4,803.72 - 3,798.53 5,979,017.03 367,455.51 0.30 6,119.01 MWD +IFR -AK- CAZ -SC (2) 8,061.08 67.39 321.55 4,237.57 4,185.30 4,871.93 - 3,852.79 5,979,086.15 367,402.43 0.74 6,206.08 MWD +IFR -AK- CAZ -SC (2) 8,156.21 67.57 321.06 4,274.01 4,221.74 4,940.51 - 3,907.72 5,979,155.66 367,348.68 0.51 6,293.86 MWD +IFR -AK- CAZ -SC (2) 8,252.45 67.30 320.83 4,310.94 4,258.67 5,009.52 - 3,963.72 5,979,225.62 367,293.89 0.36 6,382.61 MWD +IFR -AK- CAZ -SC (2) 8,347.20 67.17 321.14 4,347.60 4,295.33 5,077.41 - 4,018.72 5,979,294.43 367,240.06 0.33 6,469.85 MWD +IFR -AK- CAZ -SC (2) 11/23/2009 12 :53 :41PM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well Rig: CD2 -76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Well: Rig: CD2 - 76 ; North Reference: True Wellborn: CD2 - 76PB1 Survey Calculation Method: Minimum Curvature Design: CD2 - 76PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N -S +F-! -W Northing Easting DLS Section (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( °/1001 (ft) Survey Tool Name 8,442.82 66.99 321.47 4,384.84 4,332.57 5,146.15 - 4,073.78 5,979,364.10 367,186.20 0.37 6,557.83 MWD +IFR -AK- CAZ -SC (2) 8,537.82 67.25 321.00 4,421.78 4,369.51 5,214.39 - 4,128.58 5,979,433.27 367,132.58 0.53 6,645.25 MWD +IFR -AK- CAZ -SC (2) 8,633.23 66.80 321.34 4,459.02 4,406.75 5,282.82 - 4,183.66 5,979,502.63 367,078.69 0.57 6,732.98 MWD +IFR -AK- CAZ -SC (2) 8,728.34 66.71 320.97 4,496.56 4,444.29 5,350.88 - 4,238.47 5,979,571.62 367,025.06 0.37 6,820.27 MWD +IFR -AK- CAZ -SC (2) 8,823.94 66.92 320.81 4,534.19 4,481.92 5,419.07 - 4,293.91 5,979,640.75 366,970.81 0.27 6,908.02 MWD +IFR -AK- CAZ -SC (2) 8,919.04 67.18 320.90 4,571.28 4,519.01 5,486.99 - 4,349.19 5,979,709.60 366,916.71 0.29 6,995.46 MWD +IFR -AK- CAZ -SC (2) 9,014.08 66.80 321.37 4,608.43 4,556.16 5,555.10 - 4,404.08 5,979,778.64 366,863.00 0.61 7,082.82 MWD +IFR -AK- CAZ -SC (2) 9,109.18 66.71 321.70 4,645.96 4,593.69 5,623.52 - 4,458.43 5,979,847.97 366,809.83 0.33 7,170.12 MWD +IFR -AK- CAZ -SC (2) 9,204.60 66.78 321.26 4,683.63 4,631.36 5,692.11 - 4,513.03 5,979,917.48 366,756.42 0.43 7,257.71 MWD +IFR -AK- CAZ -SC (2) 9,299.69 66.84 321.22 4,721.08 4,668.81 5,760.27 - 4,567.75 5,979,986.57 366,702.89 0.07 7,345.01 MWD +IFR -AK- CAZ -SC (2) 9,394.95 66.43 321.70 4,758.86 4,706.59 5,828.66 - 4,622.24 5,980,055.89 366,649.59 0.63 7,432.37 MWD +IFR -AK- CAZ -SC (2) 9,488.83 66.44 321.78 4,796.39 4,744.12 5,896.23 - 4,675.53 5,980,124.35 366,597.47 0.08 7,518.36 MWD +IFR -AK- CAZ -SC (2) 9,584.77 66.30 321.55 4,834.84 4,782.57 5,965.18 - 4,730.04 5,980,194.22 366,544.15 0.26 7,606.18 MWD +IFR -AK- CAZ -SC (2) 9,679.73 66.84 320.92 4,872.60 4,820.33 6,033.11 - 4,784.60 5,980,263.08 366,490.78 0.83 7,693.21 MWD +IFR -AK- CAZ -SC (2) 9,774.87 66.86 321.64 4,910.01 4,857.74 6,101.37 - 4,839.32 5,980,332.25 366,437.24 0.70 7,780.59 MWD +IFR -AK- CAZ -SC (2) 9,870.10 66.58 321.67 4,947.64 4,895.37 6,169.97 - 4,893.59 5,980,401.78 366,384.17 0.30 7,867.99 MWD +IFR -AK- CAZ -SC (2) 9,965.79 66.45 321.50 4,985.78 4,933.51 6,238.74 - 4,948.12 5,980,471.46 366,330.83 0.21 7,955.68 MWD +IFR -AK- CAZ -SC (2) 10,060.34 66.44 321.69 5,023.56 4,971.29 6,306.66 - 5,001.96 5,980,540.29 366,278.16 0.18 8,042.27 MWD +IFR -AK- CAZ -SC (2) 10,155.69 66.29 321.31 5,061.79 5,009.52 6,375.02 - 5,056.34 5,980,609.57 366,224.97 0.40 8,129.54 MWD +IFR -AK- CAZ -SC (2) 10,250.19 66.81 321.45 5,099.40 5,047.13 6,442.75 - 5,110.45 5,980,678.22 366,172.04 0.57 8,216.15 MWD +IFR -AK- CAZ -SC (2) 10,345.49 66.78 321.15 5,136.95 5,084.68 6,511.11 - 5,165.22 5,980,747.51 366,118.46 0.29 8,303.64 MWD +IFR -AK- CAZ -SC (2) 10,440.89 66.92 321.39 5,174.45 5,122.18 6,579.54 - 5,220.10 5,980,816.86 366,064.77 0.27 8,391.26 MWD +IFR -AK- CAZ -SC (2) 10,536.02 66.63 320.67 5,211.97 5,159.70 6,647.51 - 5,275.08 5,980,885.76 366,010.97 0.76 8,478.56 MWD +IFR -AK- CAZ -SC (2) 10,630.50 66.52 320.35 5,249.53 5,197.26 6,714.41 - 5,330.21 5,980,953.59 365,957.00 0.33 8,565.09 MWD +IFR -AK- CAZ -SC (2) 10,725.59 66.77 320.32 5,287.22 5,234.95 6,781.61 - 5,385.93 5,981,021.74 365,902.44 0.26 8,652.21 MWD +IFR -AK- CAZ -SC (2) 10,820.31 66.98 320.28 5,324.42 5,272.15 6,848.64 - 5,441.57 5,981,089.70 365,847.97 0.23 8,739.14 MWD +IFR -AK- CAZ -SC (2) 10,915.64 66.78 320.12 5,361.85 5,309.58 6,915.99 - 5,497.69 5,981,158.01 365,793.01 0.26 8,826.62 MWD +IFR -AK- CAZ -SC (2) 11,009.97 66.66 320.23 5,399.14 5,346.87 6,982.54 - 5,553.19 5,981,225.49 365,738.68 0.17 8,913.08 MWD +IFR -AK- CAZ -SC (2) 11,105.36 66.45 319.99 5,437.09 5,384.82 7,049.69 - 5,609.31 5,981,293.59 365,683.72 0.32 9,000.39 MWD +IFR -AK- CAZ -SC (2) 11,200.68 66.64 319.99 5,475.03 5,422.76 7,116.67 - 5,665.53 5,981,361.52 365,628.66 0.20 9,087.62 MWD +IFR -AK- CAZ -SC (2) 11,296.29 66.98 320.51 5,512.68 5,460.41 7,184.24 - 5,721.73 5,981,430.04 365,573.64 0.61 9,175.32 MWD +IFR -AK- CAZ -SC (2) 11,391.31 67.03 320.83 5,549.80 5,497.53 7,251.89 - 5,777.16 5,981,498.63 365,519.38 0.31 9,262.64 MWD +IFR -AK- CAZ -SC (2) 11,486.42 66.86 321.92 5,587.05 5,534.78 7,320.26 - 5,831.79 5,981,567.92 365,465.94 1.07 9,350.06 MWD +IFR -AK- CAZ -SC (2) 11,581.56 67.13 322.39 5,624.23 5,571.96 7,389.42 - 5,885.52 5,981,637.98 365,413.41 0.54 9,437.59 MWD +IFR -AK- CAZ -SC (2) 11,676.96 66.17 322.07 5,662.04 5,609.77 7,458.65 - 5,939.17 5,981,708.12 365,360.97 1.05 9,525.13 MWD +IFR -AK- CAZ -SC (2) 11,772.23 65.97 321.58 5,700.68 5,648.41 7,527.11 - 5,992.99 5,981,777.49 365,308.33 0.51 9,612.15 MWD +IFR -AK- CAZ -SC (2) 11,867.73 65.99 321.87 5,739.56 5,687.29 7,595.59 - 6,047.02 5,981,846.88 365,255.49 0.28 9,699.31 MWD +IFR -AK- CAZ -SC (2) 11,963.17 66.25 321.50 5,778.19 5,725.92 7,664.06 - 6,101.13 5,981,916.27 365,202.57 0.45 9,786.51 MWD +IFR -AK- CAZ -SC (2) 12,058.61 66.46 320.81 5,816.47 5,764.20 7,732.15 - 6,155.96 5,981,985.29 365,148.92 0.70 9,873.83 MWD +IFR -AK- CAZ -SC (2) 12,151.70 67.24 321.03 5,853.07 5,800.80 7,798.60 - 6,209.92 5,982,052.64 365,096.11 0.87 9,959.30 MWD +IFR -AK- CAZ -SC (2) 11/23/2009 12:53:41 PM Page 5 COMPASS 2003.16 Build 69 • ! ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well Rig: CD2 -76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: ! CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Well: Rig: CD2 - 76 North Reference: True Welibore: CD2 - 76PB1 Survey Calculation Method: Minimum Curvature Design: CD2 - 76PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!-S +E/ -W Northing Easting ! ' DLS ! Section (ft) ( °) O (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Toot Name 12,245.61 67.65 321.04 5,889.09 5,836.82 7,866.03 - 6,264.46 5,982,121.00 365,042.75 0.44 10,045.91 MWD +IFR -AK- CAZ -SC (2) 12,337.08 67.12 320.98 5,924.26 5,871.99 7,931.66 - 6,317.58 5,982,187.52 364,990.76 0.58 10,130.23 MWD +IFR -AK- CAZ -SC (2) 12,431.63 66.65 320.75 5,961.38 5,909.11 7,999.11 - 6,372.47 5,982,255.90 364,937.05 0.55 10,217.06 MWD +IFR -AK- CAZ -SC (2) 12,523.16 66.85 320.13 5,997.51 5,945.24 8,063.94 - 6,426.03 5,982,321.64 364,884.61 0.66 10,300.99 MWD +IFR -AK- CAZ -SC (2) 12,615.32 67.12 320.07 6,033.54 5,981.27 8,129.02 - 6,480.44 5,982,387.64 364,831.33 0.30 10,385.62 MWD +IFR -AK- CAZ -SC (2) 12,706.74 67.79 320.10 6,068.59 6,016.32 8,193.78 - 6,534.61 5,982,453.31 364,778.28 0.73 10,469.86 MWD +IFR -AK- CAZ -SC (2) 12,797.99 68.06 320.16 6,102.89 6,050.62 8,258.68 - 6,588.82 5,982,519.13 364,725.20 0.30 10,554.22 MWD +IFR -AK- CAZ -SC (2) 12,887.54 68.04 320.40 6,136.36 6,084.09 8,322.56 - 6,641.90 5,982,583.91 364,673.23 0.25 10,637.11 MWD +IFR -AK- CAZ -SC (2) 12,982.56 67.52 320.98 6,172.30 6,120.03 8,390.62 - 6,697.63 5,982,652.91 364,618.69 0.79 10,724.92 MWD +IFR -AK- CAZ -SC (2) 13,074.44 67.47 321.09 6,207.46 6,155.19 8,456.62 - 6,751.00 5,982,719.81 364,566.46 0.12 10,809.69 MWD +IFR -AK- CAZ -SC (2) 13,168.53 66.99 321.76 6,243.88 6,191.61 8,524.45 - 6,805.10 5,982,788.55 364,513.54 0.83 10,896.36 MWD +IFR -AK- CAZ -SC (2) 13,261.28 66.31 321.70 6,280.64 6,228.37 8,591.30 - 6,857.84 5,982,856.30 364,461.96 0.74 10,981.45 MWD +IFR -AK- CAZ -SC (2) 13,354.89 66.58 321.63 6,318.05 6,265.78 8,658.61 - 6,911.07 5,982,924.50 364,409.90 0.30 11,067.19 MWD +IFR -AK- CAZ -SC (2) 13,446.12 66.97 321.42 6,354.03 6,301.76 8,724.24 - 6,963.23 5,982,991.02 364,358.88 0.48 11,150.94 MWD +IFR -AK- CAZ -SC (2) 13,539.44 67.05 321.96 6,390.47 6,338.20 8,791.65 - 7,016.48 5,983,059.33 364,306.79 0.54 11,236.78 MWD +IFR -AK- CAZ -SC (2) 13,631.97 66.18 321.55 6,427.20 6,374.93 8,858.35 - 7,069.05 5,983,126.92 364,255.38 1.02 11,321.65 MWD +IFR -AK- CAZ -SC (2) 13,726.54 66.29 321.45 6,465.31 6,413.04 8,926.09 - 7,122.93 5,983,195.56 364,202.68 0.15 11,408.11 MWD +IFR -AK- CAZ -SC (2) 13,818.13 66.94 321.00 6,501.66 6,449.39 8,991.63 - 7,175.58 5,983,261.99 364,151.17 0.84 11,492.08 MWD +IFR -AK- CAZ -SC (2) 13,910.85 67.07 320.93 6,537.88 6,485.61 9,057.93 - 7,229.34 5,983,329.20 364,098.56 0.16 11,577.31 MWD +IFR -AK- CAZ -SC (2) 14,004.88 67.00 320.25 6,574.57 6,522.30 9,124.82 - 7,284.30 5,983,397.02 364,044.76 0.67 11,663.74 MWD +IFR -AK- CAZ -SC (2) 14,098.06 67.06 320.26 6,610.94 6,558.67 9,190.78 - 7,339.15 5,983,463.91 363,991.05 0.07 11,749.35 MWD +IFR -AK- CAZ -SC (2) 14,191.57 66.36 319.74 6,647.91 6,595.64 9,256.58 - 7,394.36 5,983,530.64 363,936.99 0.91 11,835.03 MWD +IFR -AK- CAZ -SC (2) 14,284.40 66.21 320.57 6,685.24 6,632.97 9,321.83 - 7,448.82 5,983,596.81 363,883.67 0.83 11,919.83 MWD +IFR -AK- CAZ -SC (2) 14,377.37 66.59 320.86 6,722.46 6,670.19 9,387.77 - 7,502.76 5,983,663.67 363,830.87 0.50 12,004.88 MWD +IFR -AK- CAZ -SC (2) 14,470.42 66.12 320.92 6,759.78 6,707.51 9,453.91 - 7,556.53 5,983,730.71 363,778.25 0.51 12,089.99 MWD +IFR -AK- CAZ -SC (2) 14,563.83 66.77 320.66 6,797.11 6,744.84 9,520.26 - 7,610.66 5,983,797.97 363,725.27 0.74 12,175.48 MWD +IFR -AK- CAZ -SC (2) 14,658.26 66.98 320.66 6,834.20 6,781.93 9,587.42 - 7,665.71 5,983,866.07 363,671.39 0.22 12,262.18 MWD +IFR -AK- CAZ -SC (2) 14,751.99 67.12 320.22 6,870.75 6,818.48 9,653.96 - 7,720.68 5,983,933.54 363,617.57 0.46 12,348.32 MWD +IFR -AK- CAZ -SC (2) 14,843.72 66.24 319.71 6,907.06 6,854.79 9,718.46 - 7,774.86 5,983,998.95 363,564.51 1.09 12,432.35 MWD +IFR -AK- CAZ -SC (2) 14,936.11 66.63 319.82 6,944.00 6,891.73 9,783.11 - 7,829.56 5,984,064.52 363,510.93 0.44 12,516.80 MWD +IFR -AK- CAZ -SC (2) 15,029.48 66.70 320.12 6,980.98 6,928.71 9,848.75 - 7,884.71 5,984,131.10 363,456.93 0.30 12,602.32 MWD +IFR -AK- CAZ -SC (2) 15,122.37 66.79 321.14 7,017.66 6,965.39 9,914.73 - 7,938.84 5,984,197.99 363,403.94 1.01 12,687.52 MWD +IFR -AK- CAZ -SC (2) 15,213.96 66.90 321.90 7,053.67 7,001.40 9,980.65 - 7,991.24 5,984,264.80 363,352.69 0.77 12,771.65 MWD +IFR -AK- CAZ -SC (2) 15,306.61 67.19 322.75 7,089.81 7,037.54 10,048.18 - 8,043.38 5,984,333.20 363,301.72 0.90 12,856.93 MWD +IFR -AK- CAZ -SC (2) 15,399.68 66.99 323.39 7,126.04 7,073.77 10,116.70 - 8,094.89 5,984,402.60 363,251.40 0.67 12,942.64 MWD +IFR -AK- CAZ -SC (2) 15,493.00 67.18 322.39 7,162.37 7,110.10 10,185.25 - 8,146.75 5,984,472.02 363,200.73 1.01 13,028.58 MWD +IFR -AK- CAZ -SC (2) 15,586.52 66.90 322.42 7,198.85 7,146.58 10,253.48 - 8,199.28 5,984,541.14 363,149.38 0.30 13,114.66 MWD +IFR -AK- CAZ -SC (2) 15,679.87 66.97 322.18 7,235.43 7,183.16 10,321.44 - 8,251.81 5,984,609.98 363,098.03 0.25 13,200.51 MWD +IFR -AK- CAZ -SC (2) I 15,771.05 66.84 321.12 7,271.19 7,218.92 10,387.21 - 8,303.85 5,984,676.64 363,047.14 1.08 13,284.31 MWD +IFR -AK- CAZ -SC (2) I 15,864.21 66.92 320.69 7,307.77 7,255.50 10,453.71 - 8,357.87 5,984,744.04 362,994.26 0.43 13,369.86 MWD +IFR -AK- CAZ -SC (2) 11/23/2009 12:53:41PM Page 6 COMPASS 2003.16 Build 69 • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well Rig: CD2 -76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Well: Rig: CD2 -76 North Reference: True Wellbore: CD2 -76PB1 Survey, Calculation Method: Minimum Curvature Design: CD2 -76PB1 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/-S +Ei-W Northing Easting " DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) plow) (ft) Survey Tool Name 15,957.51 66.60 320.26 7,344.59 7,292.32 10,519.83 - 8,412.43 5,984,811.09 362,940.85 0.54 13,455.43 MWD +IFR -AK- CAZ -SC (2) 16,051.88 67.65 320.17 7,381.27 7,329.00 10,586.65 - 8,468.07 5,984,878.85 362,886.37 1.12 13,542.18 MWD +IFR -AK- CAZ -SC (2) 16,142.55 70.17 320.43 7,413.90 7,361.63 10,651.73 - 8,522.10 5,984,944.85 362,833.47 2.79 13,626.60 MWD +IFR -AK- CAZ -SC (2) 16,238.95 72.14 321.02 7,445.03 7,392.76 10,722.35 - 8,579.85 5,985,016.44 362,776.95 2.12 13,717.68 MWD +IFR -AK- CAZ -SC (2) 16,332.05 74.44 321.61 7,471.80 7,419.53 10,791.95 - 8,635.58 5,985,086.99 362,722.43 2.54 13,806.74 MWD +IFR -AK- CAZ -SC (2) 16,424.43 77.31 322.82 7,494.34 7,442.07 10,862.75 - 8,690.46 5,985,158.71 362,668.78 3.36 13,896.27 MWD +IFR -AK- CAZ -SC (2) 16,517.57 79.27 323.33 7,513.25 7,460.98 10,935.66 - 8,745.25 5,985,232.54 362,615.26 2.17 13,987.46 MWD +IFR -AK- CAZ -SC (2) 16,548.00 79.27 323.33 7,518.91 7,466.64 10,959.64 - 8,763.10 5,985,256.82 362,597.82 0.00 14,017.35 PROJECTED to TD 11/23/2009 12:53:41 PM Page 7 COMPASS 2003.16 Build 69 • • ill ConocoPhillips(Alaska) Inc. Western North Slope CD2 Alpine Pad CD2 -76PB2 501032060371 Sperry Drilling Services Definitive Survey Report c 09 December, 2009 L '' Y f ' ' i Y 3 # I Sperry Drilling Services 1 • . ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well CD2 -76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Well: CD2 - 76 North Reference: True Wellborn: CD2 - 76PB2 Survey Calculation Method: Minimum Curvature Design: CD2 - 76PB2 Database: CPAI EDM Production : Project Western North Slope Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD2 - 76 Well Position +N / -S 0.00 ft Northing: 5,974,149.15ft Latitude: 70° 20' 15.293 N +E / - 0.00 ft Easting: 371,170.64ft Longitude: 151° 2'43.187W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 15.60ft Welibore CD2-76PB2 Magnetics Model Name ! Sample Date Declination Dip Angle Field Strength (°) (1 (nT) BGGM2007 11/18/2009 21.26 80.71 57,622 Design CD2- 76PB2 Audit Notes: j Version: 1.0 Phase: ACTUAL Tie On Depth: 12,615.32 Vertical Section: Depth From (TVD) +W-S +E/ -W Direction (ft) (ft) (ft) (°) 36.67 0.00 0.00 321.41 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 100.00 633.00 CD2 -76PB1 (gyro) (CD2- 76PB1) CB- GYRO -SS Camera based gyro single shot 10/19/2009 • 672.70 12,615.32 CD2 -76PB1 (mwd) (CD2- 76PB1) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 10/20/2009 12,675.00 12,976.05 CD2 -76PB2 (CD2 - 76PB2) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 11/18/2009 • Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS `- Section (ft) (°) (°) (ft) (ft)' (ft) (ft) (ft) (ft) (110(y) (ft) Survey Tool Name 36.67 0.00 0.00 36.67 -15.60 0.00 0.00 5,974,149.15 371,170.64 0.00 0.00 UNDEFINED 100.00 0.40 142.57 100.00 47.73 -0.18 0.13 5,974,148.97 371,170.77 0.63 -0.22 CB- GYRO -SS (1) 142.00 0.48 127.28 142.00 89.73 -0.40 0.36 5,974,148.75 371,171.00 0.34 -0.54 CB- GYRO -SS (1) 172.00 0.53 141.35 172.00 119.73 -0.58 0.55 5,974,148.56 371,171.18 0.44 -0.80 CB- GYRO -SS (1) 263.00 1.23 351.93 262.99 210.72 0.06 0.68 5,974,149.19 371,171.32 1.88 -0.38 CB- GYRO -SS (1) 356.00 3.73 348.51 355.90 303.63 4.01 -0.07 5,974,153.16 371,170.64 2.69 3.18 CB- GYRO -SS (1) 448.00 6.34 344.69 447.53 395.26 11.84 -2.00 5,974,161.02 371,168.84 2.86 10.51 CB- GYRO -SS (1) 541.00 8.39 341.46 539.76 487.49 23.23 -5.52 5,974,172.47 371,165.52 2.25 21.60 CB- GYRO -SS (1) 633.00 10.13 340.65 630.56 578.29 37.23 -10.33 5,974,186.55 371,160.95 1.90 35.54 CB- GYRO -SS (1) 672.70 11.19 344.87 669.58 617.31 44.24 -12.50 5,974,193.59 371,158.91 3.31 42.37 MWD +IFR -AK- CAZ -SC (2) 764.13 14.03 342.25 758.79 706.52 63.36 -18.19 5,974,212.81 371,153.54 3.17 60.87 MWD +IFR -AK- CAZ -SC (2) 856.86 15.46 342.54 848.47 796.20 85.86 -25.33 5,974,235.42 371,146.79 1.54 82.91 MWD +IFR -AK- CAZ -SC (2) 1219/2009 9:50:48AM Page 2 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: : Well CD2 - 76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Well: CD2 - 76 North Reference: True Welibore: CD2 - 76PB2 Survey Calculation Method: Minimum Curvature Design: CD2 - 76PB2 Database: CPAI EDM Production • Survey Map Map Vertical MD Inc Azi TVD TVDSS +•!•S +EI-W Northing Easting DLS Section (ft) ( °) ( °) (ft) (ft) O (ft) (ft) (ft ) ( °!100') (ft) Survey Tool Name 952.27 17.77 34 939. 88 11 - 5,974,2 37 2.46 108.48 MWD +IFR -AK- C -SC (2) 1,047.22 21.41 343.11 1,029.33 977.06 142.07 -43.59 5,974,291.94 371,129.50 3.90 138.23 MWD +IFR -AK- CAZ -SC (2) 1,140.29 22.96 341.32 1,115.50 1,063.23 175.52 -54.34 5,974,325.57 371,119.33 1.82 171.09 MWD +IFR -AK- CAZ -SC (2) 1,237.76 24.38 335.73 1,204.78 1,152.51 211.88 -68.70 5,974,362.16 371,105.60 2.72 208.46 MWD +IFR -AK- CAZ -SC (2) 1,331.96 27.18 330.97 1,289.61 1,237.34 248.43 -87.13 5,974,399.02 371,087.79 3.69 248.52 MWD +IFR -AK- CAZ -SC (2) 1,427.39 32.40 326.99 1,372.41 1,320.14 288.96 - 111.66 5,974,439.96 371,063.97 5.85 295.50 MWD +IFR -AK- CAZ -SC (2) 1,479.91 34.24 325.94 1,416.29 1,364.02 313.00 - 127.60 5,974,464.27 371,048.45 3.67 324.24 MWD +IFR -AK- CAZ -SC (2) 1,523.20 35.37 325.93 1,451.84 1,399.57 333.47 - 141.44 5,974,484.97 371,034.96 2.61 348.87 MWD +IFR -AK- CAZ -SC (2) 1,617.86 38.28 324.49 1,527.60 1,475.33 380.04 - 173.83 5,974,532.09 371,003.38 3.21 405.47 MWD +IFR -AK- CAZ -SC (2) 1,712.90 40.56 324.16 1,601.02 1,548.75 429.06 - 209.02 5,974,581.70 370,969.03 2.41 465.74 MWD +IFR -AK- CAZ -SC (2) 1,808.35 43.69 325.59 1,671.80 1,619.53 481.43 - 245.83 5,974,634.69 370,933.13 3.43 529.63 MWD +IFR -AK- CAZ -SC (2) 1,902.26 47.49 323.99 1,737.51 1,685.24 536.21 - 284.53 5,974,690.12 370,895.39 4.23 596.59 MWD +IFR -AK- CAZ -SC (2) 1,998.67 51.67 321.90 1,800.01 1,747.74 594.74 - 328.78 5,974,749.40 370,852.16 4.64 669.94 MWD +IFR -AK- CAZ -SC (2) 2,093.17 55.51 320.64 1,856.09 1,803.82 654.04 - 376.36 5,974,809.51 370,805.60 4.20 745.97 MWD +IFR -AK- CAZ -SC (2) 2,189.59 58.05 320.91 1,908.91 1,856.64 716.53 - 427.37 5,974,872.85 370,755.68 2.64 826.62 MWD +IFR -AK- CAZ -SC (2) 2,284.69 61.64 321.42 1,956.68 1,904.41 780.57 - 478.92 5,974,937.77 370,705.24 3.80 908.84 MWD +IFR -AK- CAZ -SC (2) 2,378.58 65.62 320.38 1,998.37 1,946.10 845.83 - 531.97 5,975,003.93 370,653.32 4.35 992.94 MWD +IFR -AK- CAZ -SC (2) 2,475.53 67.74 320.43 2,036.75 1,984.48 914.43 - 588.71 5,975,073.49 370,597.78 2.19 1,081.95 MWD +IFR -AK- CAZ -SC (2) 2,570.79 65.88 320.35 2,074.26 2,021.99 981.89 - 644.53 5,975,141.89 370,543.12 1.95 1,169.49 MWD +IFR -AK- CAZ -SC (2) 2,666.31 65.73 319.91 2,113.41 2,061.14 1,048.76 - 700.39 5,975,209.70 370,488.43 0.45 1,256.60 MWD +IFR -AK- CAZ -SC (2) 2,761.50 67.51 320.11 2,151.18 2,098.91 1,115.70 - 756.53 5,975,277.59 370,433.45 1.88 1,343.94 MWD +IFR -AK- CAZ -SC (2) 2,856.69 67.56 319.95 2,187.56 2,135.29 1,183.12 - 813.04 5,975,345.96 370,378.11 0.16 1,431.89 MWD +IFR -AK- CAZ -SC (2) 2,951.75 68.29 320.43 2,223.28 2,171.01 1,250.78 - 869.44 5,975,414.58 370,322.88 0.90 1,519.96 MWD +IFR -AK- CAZ -SC (2) 3,047.09 67.89 319.32 2,258.86 2,206.59 1,318.42 - 926.44 5,975,483.18 370,267.06 1.16 1,608.38 MWD +IFR -AK- CAZ -SC (2) 3,141.95 67.54 318.90 2,294.83 2,242.56 1,384.77 - 983.90 5,975,550.51 370,210.75 0.55 1,696.08 MWD +IFR -AK- CAZ -SC (2) 3,237.72 67.65 319.74 2,331.33 2,279.06 1,451.92 - 1,041.61 5,975,618.63 370,154.21 0.82 1,784.56 MWD +IFR -AK- CAZ -SC (2) 3,332.90 67.43 319.61 2,367.70 2,315.43 1,518.98 - 1,098.54 5,975,686.65 370,098.45 0.26 1,872.48 MWD +IFR -AK- CAZ -SC (2) 3,346.49 67.68 320.02 2,372.89 2,320.62 1,528.57 - 1,106.64 5,975,696.39 370,090.51 3.34 1,885.04 MWD +IFR -AK- CAZ -SC (2) 3,401.65 68.89 319.56 2,393.29 2,341.02 1,567.71 - 1,139.72 5,975,736.08 370,058.11 2.33 1,936.26 MWD +IFR -AK- CAZ -SC (2) 3,497.00 68.45 319.39 2,427.98 2,375.71 1,635.22 - 1,197.44 5,975,804.57 370,001.57 0.49 2,025.03 MWD +IFR -AK- CAZ -SC (2) 3,591.84 67.78 320.39 2,463.33 2,411.06 1,702.53 - 1,254.13 5,975,872.83 369,946.04 1.21 2,113.00 MWD +IFR -AK- CAZ -SC (2) 3,686.93 66.96 320.58 2,499.92 2,447.65 1,770.24 - 1,309.98 5,975,941.48 369,891.37 0.88 2,200.76 MWD +IFR -AK- CAZ -SC (2) 3,781.98 66.49 320.30 2,537.47 2,485.20 1,837.55 - 1,365.59 5,976,009.74 369,836.93 0.56 2,288.06 MWD +IFR -AK- CAZ -SC (2) 3,877.18 65.95 319.85 2,575.86 2,523.59 1,904.36 - 1,421.50 5,976,077.49 369,782.18 0.71 2,375.15 MWD +IFR -AK- CAZ -SC (2) 3,972.16 65.77 319.30 2,614.71 2,562.44 1,970.34 - 1,477.70 5,976,144.43 369,727.12 0.56 2,461.78 MWD +IFR -AK- CAZ -SC (2) 4,067.27 66.08 319.29 2,653.50 2,601.23 2,036.17 - 1,534.33 5,976,211.21 369,671.64 0.33 2,548.56 MWD +IFR -AK- CAZ -SC (2) 4,162.18 65.36 319.37 2,692.53 2,640.26 2,101.79 - 1,590.72 5,976,277.78 369,616.40 0.76 2,635.02 MWD +IFR -AK- CAZ -SC (2) 4,257.11 65.01 319.15 2,732.37 2,680.10 2,167.07 - 1,646.95 5,976,344.02 369,561.30 0.42 2,721.12 MWD +IFR -AK- CAZ -SC (2) 4,351.98 64.51 318.97 2,772.83 2,720.56 2,231.90 - 1,703.18 5,976,409.80 369,506.19 0.55 2,806.86 MWD +IFR -AK- CAZ -SC (2) 4,447.10 64.42 319.66 2,813.83 2,761.56 2,296.98 - 1,759.13 5,976,475.83 369,451.37 0.66 2,892.63 MWD +IFR -AK- CAZ -SC (2) 12/9/2009 9:50:48AM Page 3 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ! - ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well CD2 - 76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Well: CD2 -76 North Reference: True Wellbore: CD2 - 76PB2 Survey, Calculation Method: Minimum Curvature Design: CD2 - 76PB2 Database: `: ! CPAI EDM Production Survey Map Map Vertical MD Inc Az) TVD TVDSS 4+1/-S +EI-W Northing Easting DLS Section (ft) (°) C) (ft) (ft) (ft) (ft) (ft) (ft) ( (ft) Survey Tool Name 4,542.33 63.98 319.67 2,855.28 2,803.01 2,362.34 - 1,814.62 5,976,542.12 369,397.01 0.46 2,978.33 MWD +IFR -AK- CAZ -SC (2) 4,632.23 63.92 320.40 2,894.76 2,842.49 2,424.24 - 1,866.50 5,976,604.90 369,346.21 0.73 3,059.07 MWD +IFR -AK- CAZ -SC (2) 4,728.07 63.51 320.48 2,937.20 2,884.93 2,490.49 - 1,921.23 5,976,672.07 369,292.63 0.43 3,144.99 MWD +IFR -AK- CAZ -SC (2) 4,827.27 63.10 321.63 2,981.76 2,929.49 2,559.41 - 1,976.94 5,976,741.94 369,238.12 1.12 3,233.61 MWD +IFR -AK- CAZ -SC (2) 4,922.40 62.62 321.42 3,025.16 2,972.89 2,625.69 - 2,029.61 5,976,809.10 369,186.60 0.54 3,318.27 MWD +IFR -AK- CAZ -SC (2) 5,017.87 63.81 322.59 3,068.18 3,015.91 2,692.85 - 2,082.07 5,976,877.15 369,135.31 1.66 3,403.49 MWD +IFR -AK- CAZ -SC (2) 5,112.83 65.69 322.18 3,108.69 3,056.42 2,760.88 - 2,134.49 5,976,946.07 369,084.07 2.02 3,489.36 MWD +IFR -AK- CAZ -SC (2) 5,208.37 66.85 322.11 3,147.13 3,094.86 2,829.94 - 2,188.16 5,977,016.03 369,031.60 1.22 3,576.81 MWD +IFR -AK- CAZ -SC (2) 5,303.58 67.23 322.93 3,184.27 3,132.00 2,899.51 - 2,241.50 5,977,086.50 368,979.46 0.89 3,664.46 MWD +IFR -AK- CAZ -SC (2) 5,398.80 67.85 322.91 3,220.65 3,168.38 2,969.71 - 2,294.56 5,977,157.60 368,927.62 0.65 3,752.43 MWD +IFR -AK- CAZ -SC (2) 5,493.89 68.24 322.69 3,256.20 3,203.93 3,039.96 - 2,347.88 5,977,228.75 368,875.52 0.46 3,840.59 MWD +IFR -AK- CAZ -SC (2) 5,589.19 68.17 322.78 3,291.59 3,239.32 3,110.38 - 2,401.46 5,977,300.07 368,823.16 0.11 3,929.06 MWD +IFR -AK- CAZ -SC (2) 5,684.64 68.45 322.57 3,326.86 3,274.59 3,180.91 - 2,455.24 5,977,371.51 368,770.61 0.36 4,017.73 MWD +IFR -AK- CAZ -SC (2) 5,779.70 68.23 322.68 3,361.95 3,309.68 3,251.12 - 2,508.87 5,977,442.62 368,718.20 0.26 4,106.06 MWD +IFR -AK- CAZ -SC (2) 5,874.56 67.98 321.10 3,397.33 3,345.06 3,320.37 - 2,563.19 5,977,512.79 368,665.08 1.57 4,194.07 MWD +IFR -AK- CAZ -SC (2) 5,969.70 68.46 320.95 3,432.63 3,380.36 3,389.05 - 2,618.75 5,977,582.42 368,610.71 0.53 4,282.41 MWD +IFR -AK- CAZ -SC (2) 6,064.50 68.24 320.74 3,467.60 3,415.33 3,457.38 - 2,674.39 5,977,651.68 368,556.26 0.31 4,370.52 MWD +IFR -AK- CAZ -SC (2) 6,159.61 67.73 320.28 3,503.26 3,450.99 3,525.43 - 2,730.46 5,977,720.68 368,501.36 0.70 4,458.68 MWD +IFR -AK- CAZ -SC (2) 6,253.92 67.86 319.73 3,538.90 3,486.63 3,592.32 - 2,786.58 5,977,788.52 368,446.41 0.56 4,545.97 MWD +IFR -AK- CAZ -SC (2) 6,351.96 67.99 319.06 3,575.74 3,523.47 3,661.30 - 2,845.71 5,977,858.49 368,388.47 0.65 4,636.77 MWD +IFR -AK- CAZ -SC (2) 6,444.80 68.72 318.33 3,609.99 3,557.72 3,726.12 - 2,902.67 5,977,924.28 368,332.64 1.07 4,722.96 MWD +IFR -AK- CAZ -SC (2) 6,540.17 68.39 318.00 3,644.86 3,592.59 3,792.26 - 2,961.88 5,977,991.42 368,274.58 0.47 4,811.59 MWD +IFR -AK- CAZ -SC (2) 6,634.47 67.65 318.01 3,680.15 3,627.88 3,857.24 - 3,020.39 5,978,057.40 368,217.21 0.78 4,898.88 MWD +IFR -AK- CAZ -SC (2) 6,728.69 67.51 317.33 3,716.09 3,663.82 3,921.63 - 3,079.04 5,978,122.78 368,159.68 0.68 4,985.79 MWD +IFR -AK- CAZ -SC (2) 6,823.99 66.90 316.55 3,753.01 3,700.74 3,985.83 - 3,139.02 5,978,187.99 368,100.81 0.99 5,073.38 MWD +IFR -AK- CAZ -SC (2) 6,921.61 67.51 318.53 3,790.83 3,738.56 4,052.22 - 3,199.77 5,978,255.41 368,041.22 1.97 5,163.17 MWD +IFR -AK- CAZ -SC (2) 7,016.59 67.38 319.18 3,827.26 3,774.99 4,118.27 - 3,257.48 5,978,322.44 367,984.65 0.65 5,250.79 MWD +IFR -AK- CAZ -SC (2) 7,111.83 67.20 320.26 3,864.03 3,811.76 4,185.29 - 3,314.28 5,978,390.42 367,929.02 1.06 5,338.61 MWD +IFR -AK- CAZ -SC (2) 7,206.44 66.94 320.96 3,900.90 3,848.63 4,252.63 - 3,369.58 5,978,458.70 367,874.89 0.73 5,425.73 MWD +IFR -AK- CAZ -SC (2) 7,301.42 66.77 321.85 3,938.23 3,885.96 4,320.89 - 3,424.06 5,978,527.88 367,821.59 0.88 5,513.07 MWD +IFR -AK- CAZ -SC (2) 7,396.01 66.73 322.46 3,975.57 3,923.30 4,389.52 - 3,477.38 5,978,597.40 367,769.47 0.59 5,599.97 MWD +IFR -AK- CAZ -SC (2) 7,491.05 66.78 322.62 4,013.08 3,960.81 4,458.84 - 3,530.49 5,978,667.62 367,717.56 0.16 5,687.28 MWD +IFR -AK- CAZ -SC (2) 7,585.91 66.78 322.35 4,050.48 3,998.21 4,527.99 - 3,583.58 5,978,737.66 367,665.67 0.26 5,774.44 MWD +IFR -AK- CAZ -SC (2) 7,680.58 66.92 322.48 4,087.70 4,035.43 4,596.97 - 3,636.67 5,978,807.54 367,613.77 0.19 5,861.47 MWD +IFR -AK- CAZ -SC (2) 7,775.27 66.93 322.34 4,124.81 4,072.54 4,665.99 - 3,689.81 5,978,877.46 367,561.83 0.14 5,948.57 MWD +IFR -AK- CAZ -SC (2) 7,870.47 66.43 321.54 4,162.49 4,110.22 4,734.83 - 3,743.70 5,978,947.21 367,509.13 0.93 6,035.99 MWD +IFR -AK- CAZ -SC (2) 7,966.43 66.70 321.44 4,200.66 4,148.39 4,803.72 - 3,798.53 5,979,017.03 367,455.51 0.30 6,124.03 MWD +IFR -AK- CAZ -SC (2) 8,061.08 67.39 321.55 4,237.57 4,185.30 4,871.93 - 3,852.79 5,979,086.15 367,402.43 0.74 6,211.19 MWD +IFR -AK- CAZ -SC (2) 8,156.21 67.57 321.06 4,274.01 4,221.74 4,940.51 - 3,907.72 5,979,155.66 367,348.68 0.51 6,299.06 MWD +IFR -AK- CAZ -SC (2) 8,252.45 67.30 320.83 4,310.94 4,258.67 5,009.52 - 3,963.72 5,979,225.62 367,293.89 0.36 6,387.93 MWD +IFR -AK- CAZ -SC (2) 12/9/2009 9:50:48AM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well CD2 -76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) @ 52.27ft ( Doyon 19) Site: CD2 Alpine Pad MD Reference: ! CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Well: - CD2 - 76 North Reference: True Welibore: CD2 - 76PB2 Survey Calculation Method :. r Minimum Curvature Design: CD2 - 76PB2 Database: CPAI EDM Production S urvey Map Map Vertical MD Inc Azl TVD TVDSS +N/-S +E/ -W Northing Easting _ ' DLS Section (ft) ( (°) (ft) (ft) (ft) (0) (ft) (ft) (°/100') (ft) Survey Tool Name 8,347.20 67.17 321.14 4,347.60 4,295.33 5,077.41 - 4,018.72 5,979,294.43 367,240.06 0.33 6,475.30 MWD +IFR -AK- CAZ -SC (2) 8,442.82 66.99 321.47 4,384.84 4,332.57 5,146.15 - 4,073.78 5,979,364.10 367,186.20 0.37 6,563.37 MWD +IFR -AK- CAZ -SC (2) 8,537.82 67.25 321.00 4,421.78 4,369.51 5,214.39 - 4,128.58 5,979,433.27 367,132.58 0.53 6,650.89 MWD +IFR -AK- CAZ -SC (2) 8,633.23 66.80 321.34 4,459.02 4,406.75 5,282.82 - 4,183.66 5,979,502.63 367,078.69 0.57 6,738.73 MWD +IFR -AK- CAZ -SC (2) 8,728.34 66.71 320.97 4,496.56 4,444.29 5,350.88 - 4,238.47 5,979,571.62 367,025.06 0.37 6,826.12 MWD +IFR -AK- CAZ -SC (2) 8,823.94 66.92 320.81 4,534.19 4,481.92 5,419.07 - 4,293.91 5,979,640.75 366,970.81 0.27 6,914.00 MWD +IFR -AK- CAZ -SC (2) 8,919.04 67.18 320.90 4,571.28 4,519.01 5,486.99 - 4,349.19 5,979,709.60 366,916.71 0.29 7,001.57 MWD +IFR -AK- CAZ -SC (2) 9,014.08 66.80 321.37 4,608.43 4,556.16 5,555.10 - 4,404.08 5,979,778.64 366,863.00 0.61 7,089.04 MWD +IFR -AK- CAZ -SC (2) 9,109.18 66.71 321.70 4,645.96 4,593.69 5,623.52 - 4,458.43 5,979,847.97 366,809.83 0.33 7,176.42 MWD +IFR -AK- CAZ -SC (2) 9,204.60 66.78 321.26 4,683.63 4,631.36 5,692.11 - 4,513.03 5,979,917.48 366,756.42 0.43 7,264.09 MWD +IFR -AK- CAZ -SC (2) 9,299.69 66.84 321.22 4,721.08 4,668.81 5,760.27 - 4,567.75 5,979,986.57 366,702.89 0.07 7,351.50 MWD +IFR -AK- CAZ -SC (2) 9,394.95 66.43 321.70 4,758.86 4,706.59 5,828.66 - 4,622.24 5,980,055.89 366,649.59 0.63 7,438.95 MWD +IFR -AK- CAZ -SC (2) 9,488.83 66.44 321.78 4,796.39 4,744.12 5,896.23 - 4,675.53 5,980,124.35 366,597.47 0.08 7,525.00 MWD +IFR -AK- CAZ -SC (2) 9,584.77 66.30 321.55 4,834.84 4,782.57 5,965.18 - 4,730.04 5,980,194.22 366,544.15 0.26 7,612.89 MWD +IFR -AK- CAZ -SC (2) 9,679.73 66.84 320.92 4,872.60 4,820.33 6,033.11 - 4,784.60 5,980,263.08 366,490.78 0.83 7,700.02 MWD +IFR -AK- CAZ -SC (2) 9,774.87 66.86 321.64 4,910.01 4,857.74 6,101.37 - 4,839.32 5,980,332.25 366,437.24 0.70 7,787.50 MWD +IFR -AK- CAZ -SC (2) 9,870.10 66.58 321.67 4,947.64 4,895.37 6,169.97 - 4,893.59 5,980,401.78 366,384.17 0.30 7,874.97 MWD +IFR -AK- CAZ -SC (2) 9,965.79 66.45 321.50 4,985.78 4,933.51 6,238.74 - 4,948.12 5,980,471.46 366,330.83 0.21 7,962.74 MWD +IFR -AK- CAZ -SC (2) 10,060.34 66.44 321.69 5,023.56 4,971.29 6,306.66 - 5,001.96 5,980,540.29 366,278.16 0.18 8,049.41 MWD +IFR -AK- CAZ -SC (2) 10,155.69 66.29 321.31 5,061.79 5,009.52 6,375.02 - 5,056.34 5,980,609.57 366,224.97 0.40 8,136.76 MWD +IFR -AK- CAZ -SC (2) 10,250.19 66.81 321.45 5,099.40 5,047.13 6,442.75 - 5,110.45 5,980,678.22 366,172.04 0.57 8,223.45 MWD +IFR -AK- CAZ -SC (2) 10,345.49 66.78 321.15 5,136.95 5,084.68 6,511.11 - 5,165.22 5,980,747.51 366,118.46 0.29 8,311.04 MWD +IFR -AK- CAZ -SC (2) 10,440.89 66.92 321.39 5,174.45 5,122.18 6,579.54 - 5,220.10 5,980,816.86 366,064.77 0.27 8,398.76 MWD +IFR -AK- CAZ -SC (2) 10,536.02 66.63 320.67 5,211.97 5,159.70 6,647.51 - 5,275.08 5,980,885.76 366,010.97 0.76 8,486.18 MWD +IFR -AK- CAZ -SC (2) 10,630.50 66.52 320.35 5,249.53 5,197.26 6,714.41 - 5,330.21 5,980,953.59 365,957.00 0.33 8,572.86 MWD +IFR -AK- CAZ -SC (2) 10,725.59 66.77 320.32 5,287.22 5,234.95 6,781.61 - 5,385.93 5,981,021.74 365,902.44 0.26 8,660.15 MWD +IFR -AK- CAZ -SC (2) 10,820.31 66.98 320.28 5,324.42 5,272.15 6,848.64 - 5,441.57 5,981,089.70 365,847.97 0.23 8,747.24 MWD +IFR -AK- CAZ -SC (2) 10,915.64 66.78 320.12 5,361.85 5,309.58 6,915.99 - 5,497.69 5,981,158.01 365,793.01 0.26 8,834.89 MWD +IFR -AK- CAZ -SC (2) 11,009.97 66.66 320.23 5,399.14 5,346.87 6,982.54 - 5,553.19 5,981,225.49 365,738.68 0.17 8,921.52 MWD +IFR -AK- CAZ -SC (2) 11,105.36 66.45 319.99 5,437.09 5,384.82 7,049.69 - 5,609.31 5,981,293.59 365,683.72 0.32 9,009.01 MWD +IFR -AK- CAZ -SC (2) 11,200.68 66.64 319.99 5,475.03 5,422.76 7,116.67 - 5,665.53 5,981,361.52 365,628.66 0.20 9,096.43 MWD +IFR -AK- CAZ -SC (2) 11,296.29 66.98 320.51 5,512.68 5,460.41 7,184.24 - 5,721.73 5,981,430.04 365,573.64 0.61 9,184.30 MWD +IFR -AK- CAZ -SC (2) 11,391.31 67.03 320.83 5,549.80 5,497.53 7,251.89 - 5,777.16 5,981,498.63 365,519.38 0.31 9,271.76 MWD +IFR -AK- CAZ -SC (2) 11,486.42 66.86 321.92 5,587.05 5,534.78 7,320.26 - 5,831.79 5,981,567.92 365,465.94 1.07 9,359.27 MWD +IFR -AK- CAZ -SC (2) 11,581.56 67.13 322.39 5,624.23 5,571.96 7,389.42 - 5,885.52 5,981,637.98 365,413.41 0.54 9,446.84 MWD +IFR -AK- CAZ -SC (2) 11,676.96 66.17 322.07 5,662.04 5,609.77 7,458.65 - 5,939.17 5,981,708.12 365,360.97 1.05 9,534.41 MWD +IFR -AK- CAZ -SC (2) 11,772.23 65.97 321.58 5,700.68 5,648.41 7,527.11 - 5,992.99 5,981,777.49 365,308.33 0.51 9,621.49 MWD +IFR -AK- CAZ -SC (2) 11,867.73 65.99 321.87 5,739.56 5,687.29 7,595.59 - 6,047.02 5,981,846.88 365,255.49 0.28 9,708.72 MWD +IFR -AK- CAZ -SC (2) 11,963.17 66.25 321.50 5,778.19 5,725.92 7,664.06 - 6,101.13 5,981,916.27 365,202.57 0.45 9,795.99 MWD +IFR -AK- CAZ -SC (2) 12,058.61 66.46 320.81 5,816.47 5,764.20 7,732.15 - 6,155.96 5,981,985.29 365,148.92 0.70 9,883.42 MWD +IFR -AK- CAZ -SC (2) 12/9/2009 9 :50 :48AM Page 5 COMPASS 2003.16 Build 69 • ConocoPhillips Definitive Survey Report Company: ! ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well CD2 - 76 Project Western North Slope TVD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Site: CD2 Alpine Pad MD Reference: CD2 -76 (36.67 +15.6) © 52.27ft (Doyon 19) Wel4 CD2 - 76 North Reference: Tru Weilbore: CD2 - 76PB2 Survey? Calculation Method: Minimum Curvature Design: CD2 - 76PB2 Database: CPAI EDM Production Survey Map Map Vertical . , Mn Inc Azl TVD TVDSS +Ni-S +EI -W Northing Ea DLS Section O ( ° ( ° I (ft) O (ft) (ft) (ft) ( ( °!10 0') (ft) Survey Tool Name 12,151.70 67.24 321.03 5,853.07 5,800.80 7,798.60 - 6,209.92 5,982,052.64 365,096.11 0.87 9,969.01 MWD +IFR -AK- CAZ -S (2) 12,245.61 67.65 321.04 5,889.09 5,836.82 7,866.03 - 6,264.46 5,982,121.00 365,042.75 0.44 10,055.73 MWD +IFR -AK- CAZ -SC (2) 12,337.08 67.12 320.98 5,924.26 5,871.99 7,931.66 - 6,317.58 5,982,187.52 364,990.76 0.58 10,140.17 MWD +IFR -AK- CAZ -SC (2) 12,431.63 66.65 320.75 5,961.38 5,909.11 7,999.11 - 6,372.47 5,982,255.90 364,937.05 0.55 10,227.12 MWD +IFR -AK- CAZ -SC (2) 12,523.16 66.85 320.13 5,997.51 5,945.24 8,063.94 - 6,426.03 5,982,321.64 364,884.61 0.66 10,311.21 MWD +IFR -AK- CAZ -SC (2) 12,615.32 67.12 320.07 6,033.54 5,981.27 8,129.02 - 6,480.44 5,982,387.64 364,831.33 0.30 10,396.01 MWD +IFR -AK- CAZ -SC (2) 12,675.00 67.22 320.11 6,056.70 6,004.43 8,171.21 - 6,515.73 5,982,430.42 364,796.78 0.18 10,451.00 MWD +IFR -AK- CAZ -SC (3) 12,730.65 68.27 320.15 6,077.78 6,025.51 8,210.74 - 6,548.74 5,982,470.51 364,764.45 1.89 10,502.49 MWD +IFR -AK- CAZ -SC (3) 12,829.89 68.78 320.23 6,114.11 6,061.84 8,281.68 - 6,607.87 5,982,542.45 364,706.55 0.52 10,594.82 MWD +IFR -AK- CAZ -SC (3) 12,924.35 67.66 320.30 6,149.15 6,096.88 8,349.13 - 6,663.94 5,982,610.85 364,651.65 1.19 10,682.52 MWD +IFR -AK- CAZ -SC (3) 12,976.05 67.46 321.60 6,168.89 6,116.62 8,386.24 - 6,694.05 5,982,648.47 364,622.19 2.36 10,730.30 MWD +IFR -AK- CAZ -SC (3) 13,349.00 67.46 321.60 6,311.85 6,259.58 8,656.19 - 6,908.01 5,982,922.04 364,412.92 0.00 11,074.76 PROJECTED to TD 12/9/2009 9 :50:48AM Page 6 COMPASS 2003.16 Build 69 S WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 5, 2010 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: CD2 -76 Run Date: 12/20/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2 -76 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20603 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating rp063? _o9 Attn: Rafael Barreto 6900 Arctic Blvd. r335-9 9 Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 - 3535 rafael.barreto @hallrburton.corn A / I / 1 Date: Signed: �" '� • WELL LOG TRANSMITTAL To: State of Alaska December 10, 2009 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: MWD Formation Evaluation Logs: CD2- 76 +PB1 +PB2 AK -MW- 0006887971 CD2 -76 50- 103 - 20603 -00 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log CD2 -76 PBI 50- 103 - 20603 -70 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log CD2 -76 PB2 50- 103 - 20603 -71 2" x 5" MD Logs: 1 Color Log 2" x 5" TVD Logs: 1 Color Log Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 C)'9 -c9) b / / Office: 907 - 273 -3536 Fax: 907- 273 -3535 Bryan Ruin @ 11il urton.corn Date: Signed: Page l of 2 • • Schwartz, Guy L (DOA) From: Anderson, Nina M [ Nina .Anderson ©conocophillips.com] Sent: Friday, November 20, 2009 2:04 PM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); Robertson, Ryan G Subject: RE: CD2 -76 Drilling Update (PTD 209 -098) Guy - Per our conversation this morning, below is an update on CD2 -76 operations. Thursday afternoon a 17 ppg cement plug was set from 13,186' MD to 12,575' MD. This area covered +/- 300' of the old 9 -7/8" hole, 200' of new 6 -3/4" hole, and 100 feet inside 7 -5/8" casing. The cement job went good with full returns and no losses. When trying to pull out of the cement, swabbing was observed. The annular preventor was closed and 8 stands of DP were stripped out of the hole. The company man notified the North Slope AOGCC inspector and it was determined that once out of the hole, Doyon 19 will retest the annular. Early Friday morning the cement was tagged at 12,813' MD which is 125' below the bottom of the window but still 80 above the intersection of the old hole. The well was static and the old hole appears to be isolated. Currently a 2nd cement plug is being set from tag at 12,813' MD to the same TOC 12,575' MD. Once a sold plug has been set, a motor BHA will be picked up to sidetrack. Please let me know if you have any further questions. Thanks Nina Anderson From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, November 18, 2009 3:32 PM To: Anderson, Nina M Cc: Schwartz, Guy L (DOA); Robertson, Ryan G Subject: RE: CD2 -76 Drilling Update (PTD 209 -098) Nina, Thanks for clarifying the name change(s). Good luck plugging back and getting away from the old wellbore(s). Tom From: Anderson, Nina M [mailto: Nina .Anderson @conocophillips.com] Sent: Wednesday, November 18, 2009 3:31 PM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); Robertson, Ryan G Subject: RE: CD2 -76 Drilling Update (PTD 209 -098) Tom — Per Guy's request, we changed the name of the first lost section to CD2- 76PB1. This was to keep the names consistent. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)- 265 -6403 Cell: (907) 575 -3256 11/20/2009 k • • Page 2 of 2 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, November 18, 2009 3:10 PM To: Anderson, Nina M Cc: Schwartz, Guy L (DOA); Robertson, Ryan G Subject: RE: CD2 -76 Drilling Update (PTD 209 -098) Nina, The "short straw syndrome" again; 1. No, a new sundry is not needed. 2. I am a little confused on the well name. If the first lost section was CD2- 76PB1, then this latest lost section would be CD2 - 76PB2. If the first lost section was CD2- 176PB1, then the latest lost hole section would be CD2 - 76PB1. Regardless of the name, the first lost hole section will have 70 in the API number and this latest lost hole section will have 71. Let me know I totally haven't confused the matter. Good luck. Tom Maunder, PE AOGCC From: Anderson, Nina M [mailto: Nina .Anderson @conocophillips.com] Sent: Wednesday, November 18, 2009 2:51 PM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); Robertson, Ryan G Subject: CD2 -76 Drilling Update (PTD 209 -098) Tom — The whipstock milling assembly on CD2 -76 drilled 36' of new hole from the whipstock window set in the existing 7 -5/8" casing. An FIT to 13.5 ppg had been performed on Monday 11/16. The drilling assembly was made up and RIH with a 1.22 deg motor and PDC bit. Coming out of the window, the directional driller was having a difficult time holding toolface with the 1.22 deg motor as they tried to hold 90° left high side. The BHA wanted to continually walk right. Not being able to hold tool face, they had to rotate before eventually sliding part of the stand. As of Tuesday evening 11/17 we had drilled +/- 200' of new hole from the base of the window when it was confirmed we had drilled into the old hole. A significant increase in ROP confirmed this. Currently we are pumping off bottom with an 11.8 ppg mud weight. The plan forward is to set a cement isolation / kickoff plug in the top of CD2- 76PB1, through the just drilled CD2 - 76PB2, across the window, and up into the casing +/- 100'. Following cement, we plan to RIH with a more aggressive 1.5 deg motor to sidetrack away from the exiting casing. Please advise if a new sundry needs to be submitted and if this hole should be called CD2- 76PB1. Please let me know if you have further questions or concerns. Thanks. Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907)- 265 -6403 Cell: (907) 575 -3256 11/20/2009 -N h G y u� ` SEAN PARNELL, GOVERNOR � • 1 F p 1 ! L � F. L . ,L1 — \\ \..: R I - 11 ALASKA OIL AND GAS a£ 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -76 Sundry Number: 309 -383 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this'. day of November, 2009 Encl. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 -0360 Conoco Phillips Telephone 907 - 276 -1215 November 13 2009 R ECEI Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 AIO V 1 3 , Anchorage, Alaska 99501 11188k9 Ga Re: Sundry Permit: CD2 -176 Change to Approved Plan and Name Change Request (PT�: ula Commi 098) II�C Oraage Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to make changes to the currently approved plan and requests to change the name of the current well CD2 -176 (PTD: 209 -098). • Doyon 19 moved onto CD2 -176 on October 18 2009 with the goal of drilling a 6 -3/4" horizontal well to produce the Nechelik reservoir. The surface hole was drilled and cased to the planned depth. After drilling the 8 -3/4" intermediate hole to 16,548' MD, the 7 -5/8" casing was run to a / • depth of 12,840' MD at which point it became stuck. Attempts to free the casing were unsuccessful. Due to unstable well conditions expected in the wellbore below the 7-5/8" ` shoe, the decision was made to leave the shoe track from the first stage intermediate cement job intact. A pressure test on the casing will prove integrity of the cement shoe, and further support that the Alpine C sand penetrated by the CD2- 176PB1 wellbore is effectively isolated. The new plan is to run a whipstock assembly and exit out of the casing at a depth of roughly 12,675' MD. The well will then be drilled to a depth of 15,428' through the Alpine C reservoir (at 15179' MD / 7058' TVD). The Alpine C sand penetration will be roughly 75' laterally from the CD2- 176PB1 penetration into the Alpine C reservoir. ConocoPhillips Alaska requests a name change to the well since the Nechelik sand is no longer the target formation. Upon isolation the original well, CD2 -176 will maintain API: 50- 103 - 20603 -70 and named CD2 - 176PB1. The new well will become CD2 -76 (API: 50- 103- 20603 -00) Please find attached: • Form 10 -403 Application • Plan forward • Proposed Kick off Schematic diagram. • Proposed final well schematic If you have any questions or require further information, please contact Ryan Robertson 265- 6318 or Chip Alvord at 265 -6120. Sincerely, Ryan Robertson Attachments: Drilling Engineer CD2 -176 Well File / Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Ryan Roberston ATO 1702 -- Nina Anderson ATO 1706 Tim Schneider ATO 1768 a � • '• \ - 4 � k 11 '� STATE OF ALASKA / '11 ALAS OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate❑ Re -enter Suspended Well ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Other IS • Specify: Change approved program • Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ Change of Name ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc Development is Exploratory ❑ 209 -098 . 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P.O. Box 100360 Anchorage, AK 99510 -0360 50- 103 - 20603 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El ef)2176 • e. D 2 - No / / m 9. Property Designation (Lease Number): 10. Field /Pool(s): Colville River Field ADL 380075 • „ i Alpine Oil Pool • 11. A . PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): /G a•65P5 _ 15 35,- 12706 6068 Casing Length Size MD TVD Burst Collapse Structural Conductor 77 16” 114 114 Surface 3356 10.75" 3393 2391 3520 2480 Intermediate 12803 7.625" 12840 a 6119 6890 4790 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14. Estimated Date for 11/13/2009 For cementing casing in place 15. Well Status after proposed work: Commencing Operations: Oil 0 • Gas ❑ WDSPL El Plugged ❑ 16. Verbal Approval: Date: 11/13/2009 WINJ El GINJ El WAG ❑ Abandoned ❑ Commission Representative: Guy Schwartz GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact R. Roberston 265 - 6318 Printed Name Chip Alvord 907 - 265 - 6120 Title Drillina Manaaer 11 - 13 - 09 Signature Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: " g , , 2 Plug Integrity El BOP Test ❑ Mechanical Integrity Test El Location Clearance El 'RECEIVED Other: //�� N O V 1 3 2009 O E/ c.-A Ofot'S c tCC. oy� 4r © r � ..0 t i- A O J P i • Alaska Gil & Gas Cons. Commissi a11 Subsequent Form Required: / 6 , y� Anchorage APPROVED BY / / I 7 Approved by : .4 N.. / / COMMISSIONER THE COMMISSION Date: r ,, ,,,W / 1/(6/ R: .11 NOV 1 7 a re i� /lG6y ORIGINAL Form 10 -403 Revised 7/2009 Submit in Duplicate • • Proposed Plan 1. Clean Out Run a. RIH with 6.75" tri -cone bit and 6.75" Ghost Reamer clean out assembly b. Perform 10 minute pressure test to 3,500 psi to evaluate casing integrity above stage collar i. Drill out Halliburton stage collar at 5,878' MD ii. Continue running cleanout assembly to shoe track iii. Tag shoe track c. Perform 30 minute pressure test on 7 -5/8" casing to 3,500 psi i. Pull out of hole 2. Running Whipstock and Milling Out a. Assuming good pressure test on shoe track and casing, make up 7 -5/8" whipstock assembly and run in hole. b. Setting whipstock i. Orient whipstock to 45° left. ii. Set top of whipstock ramp at 12,675' MD iii. Mill the window out of the 7 -5/8" intermediate casing: 1. Flow at 300 gpm with 11.3 ppg LSND mud system 2. Drill 20 ft of gauge rat hole 3. Circulate bottoms up and POOH 3. Make up 6.75" Motor Assembly a. Run in hole to whipstock b. Perform FIT to 12.5 ppg EMW c. Drill out as per directional program to a TD of 15,428' MD. ORIGINAL I CD2 -176 Change to Approved Plans and Side Track for CD2 -76 Top of Whipstock 12675' MD 13' Bottom of Whipstock: 12,689' MD Space Out: 16' CD2 - 76 Top of Baffle : 12705 ' Shoe Track: 134' 7" Casing: 12840' MD / 6119' TVD 11.8 ppg CD2 -176 PB 1 Original 16548' MD / 7519' TVD . ORIGINAL • Colville River Field CD2 -76 Production Well Completion , W4 4b-: a ' `x , 1 6" Conductor to 114' r a'4 Packer Fluid mix: ;c Inhibited 9.2 - 9.4 mpg 6% KCI Brine k '; with 1500' TVD diesel car h W K.4 i 10 '/," 45.5 ppf L -80 BTC -Mod Upper Completion MD TVD n Surface Casing 1) Tubing Hanger 32' 32' @ 3394' MD / 2390' TVD 2) 4 -W 12.6 # /ft IBT -Mod Tubing (2 jts), XO cemented to surface 3) 3-1/2" 9.3 #/ft EUE -Mod Tubing 0 4) Camco TRMAXX -5E SSSV (2.812" ID) 2200' 1915' TOC @ +/ .. ! with control line to surface 5078' MD / 5) 3 -' /z' 9.3 #/ft EUE -Mod Tubing 3861' ND i ; ! 6) 3- x 1" Camco KBMG GLM w/ DV 5937' 3400' '„ 7) 3- 9.3 #/ft EUE -Mod Tubing j. lit ES Cementer 8) 3' /Z" x 1" Camco KBMG GLM w/ DV 11533' 5600' +/- 5878' MD / 9) 3'/2' 9.3 #/ft EUE -Mod Tubing .; S 0 Q 3398' TVD 10) Camco KBMG GLM (2.867" ID) w /DCK2 shear 12252' 5891' Pinned for 2500 psi casing to tbg shear 11) 3 -' /2' Tubing Joints EUE -Mod (1) 12) HES 2.813" X Profile 12292' 5907' 0 13) 3 -1/2" Tubing Joints EUE -Mod rJ 14) BOT Stinger w/ Seals and Fluted WLEG stinger 12372' 5938' Qannik Interval Stung in 20' Top +/- 7604' MD / 4057' TVD Lower Completion: MD ND 15) Baker 5 -1/2" x 7 -5/8" Flexlock Liner Hanger and ZXP Liner Top Packer w/ sealbore 12375' 5939' X/O 5-1/2" Hydril 521 Box x 4- SLHT Pin 16) 4-1/2" Blank Liner w/ SLHT 3 -1/2" 9.3 ppf L -80 EUE M 17) Orange Peel Shoe 15418' 7162' O tubing run with Jet Lube Run'n'Seal . pipe dope Calculated @ +/- 11840' MD I 7 -5/8" 29.7 ppf L -80 '' BTC Mod .r''-' ® Production Casing '_ @ 12840' MD / 6119' e: , - � / TVD ` 1 4 NOTE: If T &D numbers indicate liner rotation may be n N ` „ needed, the plan will be to run +l- 2000' 4 -M" 12.6 #/ff a 1 5 -, 1 // ` SLHT with pre - drilled pups and +1- 4000' 4 -'h" 1BTM with _- perf pups KOP 12675' MD a ` ' y ____ ' _______ i.:,. \ a - -- CD2 -176 PB1 7 '� � „� - -Mi l Alpine C 15,179' MD / 7058' "- Al. P 6 3 /4 Hole TD at ND � i . d' at 15,428' MD / 7162' TVD Perforated Interval 15,200' — 15,240' MD (40 ft) Updated 11/13/2009 2 E -line Perforation Trips 2.5" Perforating Guns (Max Swell OD = 2.676 ") Sperry Drilling Services Max Roller OD = 2.75" CD2 -76 ORIGINAL S I li dl� ConocoPhillips(Alaska) Inc. -WNS Western North Slope VIII CD2 Alpine Pad J Rig: CD2 -76 Rig: CD2 -76 1 111 I Plan: CD2- 76wp06 I Standard Proposal Report 13 November, 2009 I I' III 9 :• lVul 'l' i, r 11 11 1 CI AL Sperry Drilling Services iwuI z h 6111 ORIGINAL S S Western North Slope CD2- 76wp06 HALLIBURTON ✓ CD2 Alpine Pad ConocoPhillips Rig: CD2-76 Sperry Orin leg Rig: CD2 -76 CD2-76wp06 DDI: 6.651 SURVEY PROGRAM Depth From Depth To Survey /Plan Tool 100.00 633.00 CD2- 176PB1 (gyro) (TDed: CD2 -GfEf®1 O -SS 672.70 12615.32 CD2- 176PB1 (mwd) (TDed: CD2- MWEBIIJR- AK- CAZ -SC 12615.32 15428.55 CD2- 76wp06 (Rig: CD2 -76) MWD +IFR- AK- CAZ -SC 12000— c 0'` 0 CAP U•) " 10500— _c 1 4 -1/2" x 6 -3/4" - CD2- 176wp05 Alpine C O O 6449 Z 61; • 9000 0 7 -5/8" X 9 -7/8" KOP: DLS 13.80 TFO -45.00 7500 Tie In Point I I -12000 -10500 -9000 -7500 -6000 -4500 West( -) /East( +) (1500 ft/in) CASING DETAILS TVD MD Name Size 2385.53 3380.32 10 -3/4" x 13 -1/2" 10 -3/4 Tie In Point 6061.58 12688.60 7 -5/8" X 9 -7/8" 7 -5/8 7162.24 15428.55 4 -1/2" x 6 -3/4" 4 -1/2 KOP: DLS 13.80 TFO -45.00 C ' 6000 _ 7 - 5/8" X 9 - 7/8" O LC) ti 6750 U_ f __ a. CD2- 176wp05 Alpine C a) i o(0 n 7500 � `\% 4-1/2" x 6 -3/4" U 1 9750 10500 11250 12000 12750 13500 14250 ri a �filii^" ORIGINAL vp,� i i � 7m i ro� au�yeku f � i .ioRtai noft' or In) Easting (5000 ft/in) 1 1 1 1 I 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ' I 1 1 I 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 , i I 1 I 1 1 1 I I 1 1 I i I l I I I I 1 1_ ConocoPhillips(Alaska) Inc. -WNS CD2 -466 Date prepared: - Western North Slope CD2- 177wp02 11:39, November 13 2009 CD2 Alpine Pad CD2- 462wp05 CD. [ � -468 - CD' 0 ' f i '1 ,, .. Y, 112 a 2 -01 CD 7 ► D2 -76 \its'; -2� i �; CD2 -744 \CD o� '`," B i C �, - .1 :czL gTFB 1 — CD - -73 C C 0' 12 -� 04 — CD' -0' B A - 8 -2 \ . C12 a 1 D' C 1 wp05 _ �� ' e l l . 1'x':1 ► -28PB1 -..„___R2 :7 14"- : 1 '1144 l P 2 \ AO 4 1.4." -- 0 c - CD2 78 ` .' ;4 1 ,// r z - wwszfile:_,..,%V.1.44i1-46,,k.kX■Tk'Ago!4„.. V - a in _ _ p_k Ja.f.1 , ii41.30471111111ktri;k,,:iiiH"--111.111iiik — '— ell . .E - CD --___■;, vtgsr■- i Ilk '''. .4%,,W c lit., -19 t - .11100$1■ if : i \ 1■ - f *� '' - 43 1 1 i e,�k, - ♦ _ -s D2 -44 C -45 D2 -33 CD2 �"r ` -3 k D2 -'3A 6 e,7 °' 4; 92 t N CI 5 40• '")1 .04 - CD 41A . -4 CD2-52 D -51 - CD 1 -56 r�,r,, � . 'z. ' C c -5 • L1 - CD -1 43 ii C D - 1iwe`tr.. -1 E 32 -27 C ► loLI 2 -36 _ CD2 -60 - - CD2 -60A - ORIGINAL ''' "ii,"III"i1i",," ","" ,',, ; ��'" ''" 1 1 E astin g , ( 5000 , ftlin" "I ) ConocoPhillips(Alaska) Inc. -WNS 1, iv Western North Slope CD2 Alpine Pad pil G,II II4 Rig: CD2 -76 Rig: CD2 -76 CD2-76wp06 III S s ltli I' Drilling i pill Clearance Summary 1,1 yi k, Anticollis Report 1 13 November, 2009 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad - Rig: CD2 -76 - Rig: CD2 -76 - CD2- 76wp06 A 41 Well Coordinates: 5,973,895.84 N, 1,511,203.39 E (70° 20' 14.10" N, 151° 02' 54.51" W) "1 Datum Height: CD2 -176 (36.67 +15.6) @ 52.27ft (Doyon 19) • Scan Range: 12,675.00 to 15,428.55 ft. Measured Depth. Scan Radius is 1,739.19 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited I gli Geodetic Scale Factor Applied Version: 2003.16 Build: 69 i i Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 bM' HALLIBURTION .. ,!l�llllll•Iggqllq gq Sperry Drilling Services ORIGINAL GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:27, November 13 2009 CD2- 76wp06 Ellipsoid Color 12675.00 To 15428.55 0 - — 250 1750 2000 5000 6000 14000 1600C 250 500 2000 " "' " " " " " " " "' "' 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 —"- -' 8000 18000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 2500C 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 - 30/ 330 30 1500 1750 4500 5000 12000 14000 201 402- 176PB1 RigSurvey -60 / 300 60 0 / 360 C12- 176PB1 RI= s 30 10i 30/330 q I IIIII I i r t,l« r- 60/300 / ,/f 1 1, , I �� 60 � da e g " j ' �� • ��p � -90 / 270 90 ✓ � / !, � ya � 11 � -90 / 270 „.„.\:,,., =1' _ 111^ ' 10 7 1111111i l 1 , , \ 111 i ! rl ` f ,l l`'� 1\ \ \ ,` -120 / 240 120 1 - 120 / 240 = _ 120 201 - 150 / 210 150 -150 /210 150 50 - 180 / 180 300 -180 / 180 ORIGINAL Travelling Cylinder Azimuth (TFO +AZI) [ °] vs Centre to Centre Separation [25 ft /in] Easting (3500 ft/in) — CD2- 177wp02 Date prepared: - 11:25, November 13 2009 CD2-468 - CD2-6 C - D ` D2 -1 CD2 -465 C': � i " .c: ' :ti1Rif — CD2- 9 2- 76wp06 = - CD2 -74 CD2 -0 t PB1 - CD2- D2 -404 CD2 -► P: — � C Fa 2 -23 - C ►` - i 4 P M 2 -461 c - z Z - •D 73PG�2 •� \ '�� `' B1 - s . . . . . ) 4 ) 1 \ _ - CD2- - - o o— CD2 -7: \ - '"' `1 8PB1 CD2 -0 • i - AI I I 1 1 I V . 1 Pi I. 7 ' ' - *I - 0 • - ConocoPhillips(Alaska) Inc. -WNS - - Western North Slope CD2- 467P :1CD2 - 464 - — CD2 Alpine Pad CD2 -470 CD2- 471wp04 — - I I' Il ' - BCD $67,iII��iIIIIiI�I�iIIIIiII ' ORIGINAL Eastin III ( 350i0 ftlini) ConocoPhillips(Alaska) Inc. -WNS HALL1BURTON Western North Slope Anticollision Report for Rig: CD2 -76 - CD2- 76wp06 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad - Rig: CD2 -76 - Rig: CD2 -76 - CD2- 76wp06 Scan Range: 12,675.00 to 15,428.55 ft. Measured Depth. Scan Radius is 1,739.19 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Welibore Name - Design (ft) (ft) (ft) (ft) ft CD2 Alpine Pad CD2 -09 - CD2 -09 - CD2 -09 14,933.98 693.18 14,933.98 334.07 15,075.00 1.930 Centre Distance Pass - Major Risk CD2 -09 - CD2 -09 - CD2 -09 15,138.94 698.94 15,138.94 324.66 15,300.00 1.867 Clearance Factor Pass - Major Risk CD2 -09 - CD2 -09L1 - CD2 -09L1 14,933.98 693.18 14,933.98 334.07 15,075.00 1.930 Centre Distance Pass - Major Risk CD2 -09 - CD2 -09L1 - CD2 -09L1 15,138.94 698.94 15,138.94 324.66 15,300.00 1.867 Clearance Factor Pass - Major Risk CD2 -09 - CD2 -09PB1 - CD2 -09PB1 13,900.32 799.22 13,900.32 568.44 13,926.00 3.463 Clearance Factor Pass - Major Risk CD2 -11 - CD2 -11 - CD2 -11 15,411.24 845.36 15,411.24 442.43 15,950.00 2.098 Clearance Factor Pass - Major Risk Plan: CD2 -177 - Plan: CD2 -177 - CD2- 177wp02 13,200.00 1,301.21 13,200.00 924.65 13,125.00 3.455 Centre Distance Pass - Major Risk Plan: CD2 -177 - Plan: CD2 -177 - CD2- 177wp02 13,252.73 1,302.08 13,252.73 923.90 13,200.00 3.443 Clearance Factor Pass - Major Risk Rig: CD2 -76 - TDed: CD2- 176PB1 - CD2- 176PB1 Rig: ME= MIMI MIME ®■1 Survey tool program From To Survey /Plan Survey Tool (ft) (ft) 100.00 633.00 CB- GYRO -SS 672.70 12,615.32 MWD +IFR -AK- CAZ -SC 12,615.32 15,428.55 CD2- 76wp06 MWD +IFR -AK- CAZ -SC Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. O R YG11 A 91.23 Page 2 of 4 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTDN western North Slope Anticollision Report for Rig: CD2 -76 - CD2- 76wp06 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to CD2 -176 (36.67 +15.6) @ 52.27ft (Doyon 19). Northing and Easting are relative to Rig: CD2 -76. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150.00 ° , Grid Convergence at Surface is: -0.99 °. -B. CD2.09,CD2.09L1,CD2 -09L1 V1 Ladder CD2 - 09,002- 091 V4 �1 -B- CD2 -11 ,CD2 -11, CD2.11 V7 -B. CD2- 15,CD2- 15,CD2.15V3 • t<i 1 $ CD2- 15,CD2- 15PB1,CO2 -15PB1 V1 11' r' -1-- CD2- 15,CD2- 15PB2,CD2- 15PB2V2 1500— l ,..., -e CD2- 18,CO2.18,CD2.18 V10 p i i i hl r i .9 CD2- 18,CO2.18P51,CD2 -18PB1 V5 in ..../A $ CO2.21,c02.21,CD2 -21 V19 ----- : - ill : CD2- 21,CD2.21P81,CO2- 21PB1V7 p i i i i 49 i k1 ->f CO2- 23,CD2- 23,CD2 -23V2 co i i i i i i -e CO2- 24,CO2- 24,CD2.24V0 (O 1000 , , , PA - ►1 , -4. CD2.24,CD2.24P81,CO2 -24P81 V1 Q ( l +k� L -8- CD2- 30,CD2- 30,CD2 -30 V31 Q? i - L- , , i - CD2- 3I ,CD2- 31,CD2.31 V7 i i i i 1 F 7,irWl -- CD2- 31,CD2- 31PB1,CD2- 31PB1V4 f i i i i i 1 i i i i i -0 CD2- 404,CD2- 404,002 -404V5 CD2- 464, 002- 464, 002 -454 V0 0 X00— -8- CO2.485,CD2- 465,CD2 -465V0 i i i i 1 1 .--3- CD2- 466,CD2- 466,CD2 -466V0 C i i i i __ __ i i -- CO2- 457,CD2.467,CD2 -467 V0 ( 3 i i i i i -. CD2.467,CO2.467P131,CD2- 467PB1 V0 t.< 4+ CD2.468,C132.468,CO2 -468V0 0 ' ' ' CD2- 469,CO2.469,CD2 -469VD 0 3000 6000 9000 12000 15000 - CD2- 470,CD2- 470,002 -470w Measured Depth (3000ft/in CD2.72,CD2.72,CV1 -X- CD2 - 73,002- 73,CO -72 2.73V0 - r.n3 - 7:1 r113 71PR1 r..n3 72PR11rn 0 R to A L 23 Page 3 of 4 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Rig: CD2 -76 - CD2- 76wp06 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor r 1 I �. ; -Q- CD2 -09, CO2- 00L1,CD2.09L1 V1 I ' 1 1 --- - CD2- 09,CD2- 09PB1,CO2.09PB1V4 1000 , I , ! - 4, r .m - -_ -13- C 02 -11 ,CD2 -11 , C 02.11 V7 - 4 1 - CD2- 15,CD2- 15PB1,CD2.15PB1 V1 835 1 + : 1 .4.- CD2- 15, CD2- 15PB2,CO2.15PB2 V2 • f t I + 1 CD2.18,CO2- 18,CO2 -18V19 1 „ 1 : . . , 0 1 ;, , 1 , : t i - [ 1 � I ' '. 1 , - -+ - CD2- 18,CO2- 18PB1,CO2- 18PB1V5 - ± - ' 4 -6- CD2- 21,CO2.21,CO2 -21 V19 0 1 1 1 I 11 1 1 , 1 1 q 110 C 21,CO2.21PB1,CD2- 21PB1V7 �' I r; I r i 1 ,r ' 1 j 1 -34- CO2- 23,CD2- 23,CO2 -23 V2 o - i i 1 1 - CO2- 24,CD2.24,CO2 -24\D _ ' 1 i I : ��4$ CD2 -24, 002 -24P B 1, CD2.24P B 1 V1 _ V L - C132-3 0. CD2 -30, CD2 -30 V3 1 c 500 r I T i I 11 : ° - - i : + 1 N i .. f..4••■• CD2- 31,CD2- 31,CD2 -31 V7 3 - CD2- 31,CO2.31P81,CO2 -31PB 1 V4 as co 335 r� i I - . -.�, r $ CD2 -404 CD2 -404 CD2 -404 V5 i h • � I * F - 1 ' ILI -j— CO2 -464, CD2 -464, CD2 -464 VO Fit 1 1 1 I p 1 ` 1 -e- C D2 -465, CD2.465, CD2 -465 VO 1 253 — r i C !1 `� k f: - D2 -466, CD2 -466, 002.466 VO g - - 0 - vy r7 - � C 02-467, 002-467, 002-467 VO tl ' - � � 1 ., ' CD2- 467,CO2.467PB1,CD2- 467P81 V0 41 ,,,,, .; ,, 1 i • 4 , , , { - - CD2 -468, 002 -468, CD2 -468 VO 125 1,1 , _ :,,„ , , ::::, + -. 4 I g , 1 -.- CD2 -469, CD2 -469, 002.469 VO 0O0 • . I - -.X- 002.470, CD2 -470, CD2 -470 VD 0 I 350 75[0 E75) 1 112M I 1375D 15:00 CO2.72.0O2 -72, 002.72 V1 Measured Detth(2 . CD2 - 73,002. 73,002 -73 V0 -A- CO2 -73, CD2 -73 P B1, CD2.73P B 1 VO 0R tG/N) 1.23 Page 4 of 4 COMPASS GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:28, November 13 2009 CD2- 76wp06 Ellipsoid Color 12675.00 To 12900.00 0 250 1750 2000 5000 — 6000 14000 16001 250 500 2000 _ "` " " " " " " " "`" 2500 6000 7000 16000 18001 500 750 2500 3000 7000 8000 18000 20001 0 / 360 750 1000 3000 3500 8000 9000 20000 25001 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 - / 330 30 1500 1750 4500 5000 12000 14000 201 -60 / 300 60 0/360 50 -30 / 330 30 101 CL176PB1 RigSurve■. 41 -60 / 300 / \ 60 L 90 / 270 90 l� I D2- 176P81 RigSu �. � � 1 � I f l flf -90 / 270 - 90 r 101 1Ilf " \)\ I �` -120 / 240 120 1\ -120 / 240 _% 120 200 -150 /210 150 - 150 / 210 150 50 -180 / 180 300 -180 / 180 ORIGINAL Travelling Cylinder Azimuth (TFO +AZI) [O] vs Centre to Centre Separation [25 ft/in] • GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:30, November 13 2009 CD2- 76Wp06 Ellipsoid Color 12900.00 To 13300.00 0 250 1750 — 2000 5000 6000 14000 1600C 250 500 2000 ""`"` 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 - 2500C 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 30/ 330 30 1500 1750 4500 5000 12000 14000 201 -60 / 300 60 0/360 50,s CD2- 176PB1 RigSurveys C12- 176PB1 'igSurve s -30 ' t 30 , , , , Al io. 1 L .1 ' 11 �� ; 3 Y _ -60 / 300 ... � ] I i ' i 60 -90 / 270 90 \ / � _ -90 / 270 I ''----.14 90 101 , \I, iE, \ - 120 / 240 120 -120 / 240 25 120 200 - 150 / 210 150 -150 / 210 150 50 -180 / 180 300 -180 / 180 ORIGINAL Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:31, November 13 2009 CD2- 76wp06 Ellipsoid Color 13300.00 To 14000.00 0 250 1750 2000 5000 - _ 6000 14000 1600C 250 500 2000 """ " " "" "" """"" """' 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 16000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 2500C 300 1000 1250 3500 " 4000 9000 - 10000 1250 1500 4000 4500 10000 12000 30 / 330 30 1500 _- 1750 4500 5000 12000 14000 201 -60 / 300 60 0 / 360 C12- 176-:1 RigSurve s 50 -30 / 330 30 101 [[� -60 / 300 60 -90 / 270 90 -90 / 270 90 10: -120 / 240 120 -120 / 240 120 200 -150 /210 150 - 150 / 21: 150 50 - 180 / 180 300 -180 / 180 ORIGINAL Travelling Cylinder Azimuth (TFO +AZI) [°] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:31, November 13 2009 CD2-76wp06 Ellipsoid Color 14000.00 To 14500.00 0 250 1750 2000 5000 _ _- – _ 6000 14000 16001 250 500 2000 """" """" 2500 6000 7000 16000 18006 500 750 2500 3000 7000 8000 18000 `° 20001 0 / 360 750 1000 3000 3500 8000 9000 20000 — 25001 300 1000 1250 3500 4000 9000 10000 1250 " 1500 4000 " 4500 10000 12000 - / 330 30 1500 1750 4500 5000 12000 14000 20 -60 / 300 60 0 / 360 CF2 -176PB RigSurve's 50 -30 / 330 30 10 -60 / 300 60 -90 / 270 90 -90 / 270 90 10 -120 /240 120 -120 / 240 120 20 -150 /210 150 - 150/210 150 50 180 /180 300 -180 / 180 ORIGINAL Travelling Cylinder Azimuth (TFO +AZI) [O] vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:32, November 13 2009 CD2- 76wp06 Ellipsoid Color 14500.00 To 15000.00 0 250 1750 2000 5000 6000 14000 1600C 250 500 2000 " " " " " " " " "' °°°"- 2500 6000 7000 16000 " 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 2500C 300 1000 1250 3500 4000 9000 10000 1250 1500 4000 4500 10000 12000 -30 / 330 30 1500 1750 4500 5000 12000 14000 208 -60 / 300 60 0 / 360 C12- 176PB1 21=3 s 30 / 330 50 30 101 -60 / 300 ‘60 -90 / 270 90 -90 / 270 90 1011 -120 /240 120 -120 / 240 120 20' • - 150 / 210 150 150 / 211 150 50 - 180 / 180 300 -180 / 180 ORIGINAL Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 11:32, November 13 2009 3 CO!2.76Wp06 Ellipsoid Color 15000.00 To 15428.55 0 250 1750 2000 5000 6000 14000 1600C 250 500 2000 F °"""`' 2500 6000 7000 16000 1800C 500 750 2500 3000 7000 8000 18000 2000C 0 / 360 750 1000 3000 3500 8000 9000 20000 2500C 300 1000 1250 3500 4000 9000 — 10000 1250 1500 4000 4500 10000 12000 30/ 330 30 1500 — 1750 4500 5000 12000 14000 201 -60 / 300 60 CD2- 176PB1 RigSurveyp 0 / 360 C12 176PB1 RIME s -30 / 330 '' 30 HI - ... 10. u i 1 , 90/270 • 90 60 / 300 2 �j 60 -90 / 270 90 101 -120 /240 120 -120 / 240 25 120 200 II/ -150 /210 150 -150 / 210 150 50 - 180 / 180 300 -180 / 180 ORIGINAL Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [25 ft/in] Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, November 13, 2009 8 :32 AM To: 'Anderson, Nina M' Subject: RE: Plan Forward on CD2 -176 (PTD- 209 -0980) Nina, Have discussed below plan with commissioners and you have verbal approval to proceed as outlined below. Please submit new directional and other changes with the 403 sundry ( change approved operation) as well as the new well name..... CD2 -76 (check "other" box ). The PTD number will stay the same. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Anderson, Nina M [mailto: Nina. Anderson @conocophillips.com] Sent: Thursday, November 12, 2009 6:14 PM To: Schwartz, Guy L (DOA) Cc: Robertson, Ryan G Subject: Plan Forward on CD2 -176 (PTD - 209 -0980) Guy — Per our conversation this morning, ConocoPhillips will isolate the original well which will now be named CD2 -176 P81. Isolation will consist of a 134' cemented shoe track and a whipstock set above. The sidetracked welibore which targets only the Alpine C sand will be named CD2 -76. Below is the plan forward for CD2 -76. A sundry application for change to Approved Program along with a new well plan, outline procedure, and well schematic will be submitted. Please call with any questions or concerns. Plan Forward for CD2 -76 1. RIH with 6 -3/4" Cleanout assembly to mill out the cement and ES cementer. 2. Pressure test casing to 3500 psi for 30 minutes. 3. Continue to RIH to top of shoe track at 12,705' MD to clean any cement stringers. 4. PU Whipstock and RIH. Set whipstock +/- 50' on top of cemented shoe track at 12,675' MD. 5. Cut and mill window plus gauge hole. 6. RIH with motor and 6 -3/4" Drilling assembly. Perform LOT. 7. Drill to TD of +/- 15,429' MD +/- 200 below the Alpine C sand. 8. RIH to TD with 4 -1/2" liner with ZXP Packer, Liner Hanger, and Seal Bore Extension. Cement from liner TD back to liner hanger. 9. RIH with 3 -1/2" upper completion similar to original plan with 3 GLM's, SSSV, XN npl, locator sub, baker seal assembly. 10. Land tubing and complete well per original well plan. 11. ELine will perforate the Alpine C sand once the rig leaves. Thanks. Nina Anderson Drilling Engineer 11/13/2009 . • Page 2 of 2 Alpine Drilling Team Office: (907) - 265 -6403 Cell: (907) 575 -3256 I 11/13/2009 • • Page 1 of 2 Schwartz, Guy L (DOA) From: Regg, James B (DOA) v Sent: Friday, November 06, 2009 4:24 PM D aY - � d To: Schwartz, Guy L (DOA) Subject: FW: Well Control Incident CD2 -176 fyi Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Doyon 19 Company Man [ mailto :doyonl @conocophillips.com] Sent: Sunday, November 01, 2009 12:23 PM To: DOA AOGCC Prudhoe Bay Cc: Anderson, Nina M; Chambers, Mark A : Well Control Incident CD2- Subject el Co tro 76 1 Gentlemen here is a short break down of the well control issues we had on Doyon 19 well CD2 -176. We got back to drilling © 0100 hrs 11 -1 -09 and are drilling ahead at this time w/ 11.8 ppg mud. Initially the well was shut in with the upper pipe rams and later we switched to the annular to facilitate pipe movement during this operation. We will test the equipment used on the next trip out of the hole. If I have left out anything or you need more info p please give me a call. We were on bottom drilling ahead w/ 10.5 mud when the pump pressure decreased from 3830 psi to 3770 W e d p psi 9 ppg P P p and an increase in flow was detected. Picked up off bottom from 15662' (7228' TVD) to 15650'. Monitor well while pumping 725 gpm w/ 3770 psi. At this time the pit volume increased. Shut in well © 1319 hrs. Notified town drilling engineer, drilling manager, pad operator, and AOGCC of well control incident. Shut in pressures were SIDP 270 psi, SICP 300 psi. Circulate through choke begin losing returns stop and shut in well, monitor pressures (SIDP 270, SICP 300).Resume pumping and regain full returns. Circulated surface to surface= (14000 strokes). Maintain 11.48 ECD's. Shut down and monitor well f/ 30 minutes. Initial drill pipe pressure 190 psi; after 15 minutes, stable at 260 psi, stayed 260 psi. Initial csg pressure 210 psi, final 230 psi. Kill wt mud appears to be 11.3 ppg. Circulate and weight up from 10.5 ppg to 10.8 ppg while circulating through the choke. Maintain 11.48 to 11.52 equivalent mud weight w/ Sperry Sun PWD tools. Pumping 65 to 66 spm (275 to 277 gpm) w/ 980 to 1010 psi. Final 65 spm (273 gpm) w/ 910 psi on drill pipe, 20 psi on csg. Mud weight is 10.8 ppg to surface at midnight (10- 30-09). Shut down and monitor well f/ 30 minutes. Initial drill pipe pressure 60 psi; after 15 minutes, stable at 120 psi, stayed 120 psi. Initial csg pressure 60 psi, final 150 psi. Kill wt mud appears to be 11.2 to 11.3 ppg. Circulate and weight up from 10.8 ppg to 11.2 ppg while circulating through the choke. Maintain 11.48 to 11.52 equivalent mud weight w/ Sperry Sun PWD tools. Pumping 65 to 66 spm (275 to 277 gpm) w/ 920 to 930 psi w/ wide open choke at almost surface to surface. Final 66 spm (273 gpm) w/ 920 psi on drill pipe, 0 psi on csg. Mud weight @ shakers was 11.1 ppg at 0630 hrs. Monitor well: Initial and final dp pressure was 30 psi. Initial csg pressure was o, final 70 psi. Continue to circulate and weight up to 11.2 ppg, taking returns through the choke. Pumping 275 gpm w/ 920 psi - choke side open. 11/6/2009 • Page 2 of 2 Monitor well: Initial and final dp pressure was 30 psi. Initial and final casing pressure was 0 psi. Note: Rotate drill string with annular closed: 24k ft Ibs to break free, then 18 k ft Ibs of torque to rotate freely every 2 hours. Open choke, open annular © 0830 hrs, rotate pipe freely w/ 17.5k ft Ibs of torque. Start circulating 315 gpm w/ 1180 psi -20% flow out —ECD's 11.75 ppg. Rotate 50 rpm w/ 17.5k ft Ibs of torque. Continue circulating and weight up from 11.2 ppg to 11.5 ppg. Pumping 378 gpm w/ 1480 psi. Monitor well: Slight flow, gained less than a bbl. Continue to circulate 11.5 ppg mud, then weight up to 11.8 ppg. Initial circ rate of 350 gpm w/ 1350 psi- Final rate of 269 gpm w/ 1060 psi- 19% flow out- -ECD's 12.46 ppg. Rotate 70 rpm w/ 19.5k ft Ibs of torque. Obtain slow pump rates w/ 11.8 ppg mud. Monitor well: Slight losses. Circulate bottom's up pumping 378 gpm w/ 1685 psi- 23% flow out -12.52 ppg ECD's. Adding dyna red fine and /or nut plug fine 2 sx/10 min (12 sx per hour). Fred Herbert / Granville Rizek Doyon 19 Company Man (0) 670-4300 Fax 670 -4301 11/6/2009 • • ,(\__ ilmr-i- a , 5 --, r; (----),-, -- 10-' 1 ''FI n 'If (63 4 r r i 1 #pi , 0, 1, L, II\ IL t a 6 t r SEAN PARNELL, GOVERNOR 4 � �� W yk � � : � F y �� _>> L.,..„,, ft , ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIISSION / ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 November 6, 2009 Mr. Jack Walker Principal Production Engineer, WNS Base ConocoPhillips Alaska, Inc. 700 G Street Anchorage, Alaska 99501 RE: Request for a waiver of the gas oil ratio limitations of 20 AAC 25.240(a) for well CD2 -176 to allow for reservoir evaluation and authorization to commingle production from same well on the surface with production from other pools in the Colville River Unit. Dear Mr. Walker: By letter dated October 28, 2009, and received by the Alaska Oil and Gas Conservation Commission (Commission) on October 29, 2009, ConocoPhillips Alaska, Inc. (CPAI) as the operator of the Colville River Unit (CRU) requested a waiver, in accordance with 20 AAC 25.240(b)(3), to allow for testing of the CD2 -176 well to acquire reservoir performance data to help determine future reservoir development of a hydrocarbon accumulation that currently lies outside of any active pool in the CRU. CPAI also notified the Commission of their intent to commingle production from this well on the surface with the other pools in the CRU in accordance with 20 AAC 25.215(a). CPAI's requests are hereby granted under the conditions below. The CD2 -176 well, in the CRU, was permitted by the Commission on September 28, 2009. The purpose of the well is to test a hydrocarbon accumulation that is currently outside of any active pool. The purpose of the testing is to determine whether or not it would be appropriate to expand an existing pool, or create a new pool, to encompass the area tested by the well and to determine how to further expand development in this area. CPAI proposed testing the well for up to six months in order to gather the data necessary to optimize reservoir development decisions. It is anticipated that during prolonged testing the producing gas -oil ratio (GOR) of the well will exceed the GOR limitation established by 20 AAC 25.240(a). As such, CPAI requests a GOR waiver from the Commission under 25.240(b) in order to determine an optimum reservoir management program. 1 009 -osS" 1 • • CPAI has also notified the Commission that they intend to comply with the requirements of 25.215(a), which allows commingling of production on the surface from multiple wells provided each well is tested at least monthly. Specifically, CPAI notes that they intend to test the well and allocate production in accordance with the procedures approved and in place for the all of the pools in the CRU. The pool rules for these fields require testing of the wells at least twice per month and prescribe certain reporting requirements. Based on the above, CPAI's request for a waiver of the GOR limitations of 20 AAC 25.240(a) is GRANTED under the following conditions: 1) This waiver expires at the end of the month six months after regular production commences from the well (e.g. if production begins at any time in November 2009, this waiver will expire May 31, 2010); and 2) CPAI must inform the Commission in a timely manner if any aspect of the proposed testing program changes. The Commission takes notice that CPAI intends to produce the CD2 -176 well in compliance with the requirements of 25.215(a). The Commission imposes the criteria that production from the well be measured and allocated in accordance with the procedures stipulated in the pool rules for the other pools in the CRU. These procedures were most recently stipulated by Rule 6 Common Production Facilities and Surface Commingling, in Conservation Order 569 for the Fiord Oil Pool, which states: a. Production from the Fiord Oil Pool may be commingled with production from other CRU pools in surface facilities prior to custody transfer. b. Production shall be allocated to wells within the Fiord Oil Pool in accordance with the procedures described in Section 5.0 of ConocoPhillips' application dated November 22, 2005. c. Each producing well must be tested a minimum of twice per month. d. The Commission may require more frequent or longer tests if the allocation quality deteriorates. e. The operator shall submit a monthly report and electronic file(s) containing daily allocation data and daily test data for agency surveillance and evaluation. f. The operator shall provide the Commission with a well test and allocation review report in conjunction with an annual reservoir surveillance report. 2 il • i CPAI shall follow these procedures when measuring, allocating, and reporting production for the CD2 -176 well. DONE at Anchorage, Alaska and dated Nove ber 6, 2009. )- ) .7 7) , 0 // / / a r. ---. - ' . Daniel T. eamount, Jr. '. = K. 4 an Cathy P Foersfer Chair ommissioner Commissioner A , ` RECONSIDERATION AND APPEAL NOTICE � . ; er . ,.. o de in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as i f. ,. le = o ssion grants for good cause shown, a person affected by it may file with the Commission an application for . ,� 4 t'.tion of the matter determined by it If the notice was mailed, then the period of time shall be 23 days. An � ll- ?: '• n for reconsideration must set out the respect in which the order or decision is believed to be erroneous. h The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. 3 e Ci'' 7. 0 ciY • • r 5.--z ¥ s i ` k@ if SEAN PARNELL, GOVERNOR rt- L 1[1\ ii, L_---t- ,!, i Li Lrl, \ i 1 -1 al), 0-) k ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMDIISSION I ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 November 6, 2009 Mr. Jack Walker Principal Production Engineer, WNS Base ConocoPhillips Alaska, Inc. 700 G Street Anchorage, Alaska 99501 RE: Request for a waiver of the gas oil ratio limitations of 20 AAC 25.240(a) for well CD2 -176 to allow for reservoir evaluation and authorization to commingle production from same well on the surface with production from other pools in the Colville River Unit. Dear Mr. Walker: By letter dated October 28, 2009, and received by the Alaska Oil and Gas Conservation Commission (Commission) on October 29, 2009, ConocoPhillips Alaska, Inc. (CPAI) as the operator of the Colville River Unit (CRU) requested a waiver, in accordance with 20 AAC 25.240(b)(3), to allow for testing of the CD2 -176 well to acquire reservoir performance data to help determine future reservoir development of a hydrocarbon accumulation that currently lies outside of any active pool in the CRU. CPAI also notified the Commission of their intent to commingle production from this well on the surface with the other pools in the CRU in accordance with 20 AAC 25.215(a). CPAI's requests are hereby granted under the conditions below. The CD2 -176 well, in the CRU, was permitted by the Commission on September 28, 2009. The purpose of the well is to test a hydrocarbon accumulation that is currently outside of any active pool. The purpose of the testing is to determine whether or not it would be appropriate to expand an existing pool, or create a new pool, to encompass the area tested by the well and to determine how to further expand development in this area. CPAI proposed testing the well for up to six months in order to gather the data necessary to optimize reservoir development decisions. It is anticipated that during prolonged testing the producing gas -oil ratio (GOR) of the well will exceed the GOR limitation established by 20 AAC 25.240(a). As such, CPAI requests a GOR waiver from the Commission under 25.240(b) in order to determine an optimum reservoir management program. 1 • • 4 i Commission that they intend to comply with the requirements has also notified the Co y p y uirements q of 25.215(a), which allows commingling of production on the surface from multiple wells provided each well is tested at least monthly. Specifically, CPAI notes that they intend to test the well and allocate production in accordance with the procedures approved and in place for the all of the pools in the CRU. The pool rules for these fields require testing of the wells at least twice per month and prescribe certain reporting requirements. Based on the above, CPAI's request for a waiver of the GOR limitations of 20 AAC 25.240(a) is GRANTED under the following conditions: 1) This waiver expires at the end of the month six months after regular production commences from the well (e.g. if production begins at any time in November 2009, this waiver will expire May 31, 2010); and 2) CPAI must inform the Commission in a timely manner if any aspect of the proposed testing program changes. The Commission takes notice that CPAI intends to produce the CD2 -176 well in compliance with the requirements of 25.215(a). The Commission imposes the criteria that production from the well be measured and allocated in accordance with the procedures stipulated in the pool rules for the other pools in the CRU. These procedures were most recently stipulated by Rule 6 Common Production Facilities and Surface Commingling, in Conservation Order 569 for the Fiord Oil Pool, which states: a. Production from the Fiord Oil Pool may be commingled with production from other CRU pools in surface facilities prior to custody transfer. b. Production shall be allocated to wells within the Fiord Oil Pool in accordance with the procedures described in Section 5.0 of ConocoPhillips' application dated November 22, 2005. c. Each producing well must be tested a minimum of twice per month. d. The Commission may require more frequent or longer tests if the allocation quality deteriorates. e. The operator shall submit a monthly report and electronic file(s) containing daily allocation data and daily test data for agency surveillance and evaluation. f. The operator shall provide the Commission with a well test and allocation review report in conjunction with an annual reservoir surveillance report. 2 ,� • 0 CPAI shall follow these procedures when measuring, allocating, and reporting production for the CD2 -176 well. DONE at Anchorage, Alaska and dated Nove ber 6, 2009. 0/ )-) '; P ' 0 -/' iiii Daniel T. eamount, Jr. K. 4 an Cathy P Foers er Chair ommissioner Comm ssioner , , 1, 'iL A. b / RECONSIDERATION AND APPEAL NOTICE t z � A%, 4 .- t t,. ov de in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as Iti s te . o , a ssion grants for good cause shown, a person affected by it may file with the Commission an application for 0 ; , , tion of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An s 4. r "k� 1 , .,n for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. 3 f • . Jack Walker Principal Production Engineer, WNS Base ConocoPhillips Alaska 700 G Street CoriocoPhil lips Anchorage, AK 99501 Phone: 907.265.6822 October 28, 2009 RECEIVED Dan Seamount, Chairman OCT 2 9 2009 Alaska Oil and Gas Conservation Commission Alaska Oil & Gas Cons. Commission RE: CD2 -176 (Permit -to -Drill 209 -098) Anchorage Nechelik Undefined Pool Dear Commissioner Seamount, By this letter, ConocoPhillips Alaska, Inc., as Operator of the Colville River Unit ( "CPAI "), requests a waiver of the gas -oil ratio limitation for the CD2 -176 well (PTD 209 -098) pursuant to 20 AAC 25.240(b) and provides notice that production from this well will be commingled with other production from the Colville River Unit as described below, in compliance with 20 AAC 25.215(a). The CD2 -176 well is targeted at a bottomhole location in the Nechelik zone within the Colville River Field, but outside of all defined pools. CPAI proposes to produce the CD2 -176 well at a gas -oil ratio of the well exceeding the original gas -oil ratio of the crude by more than 100 percent to acquire performance data necessary to determine an optimum reservoir management program, as discussed with AOGCC staff on October 26, 2009. A description of the CD2 -176 Well Test Program Plan is attached to this letter. Production from the CD2 -176 well will be commingled on the surface in common production facilities with production from other Colville River Field wells. Production will be allocated to the CD2 -176 well based on well tests applying the same method as that for all Colville River Field wells according to Conservation Orders for the Alpine, Fiord, Nanuq and Qannik Oil Pools. Flaring of gas from the CD2 -176 well is not planned. To assist with planning efficient field operations, your response to this letter before November 25, 2009 would be much appreciated. If you have any questions, please contact me at 265 -6268. Sincerely, ck Walker Principal Production Engineer, WNS Base • RE: CD2 -176 (Permit -to -Drill 209 -098) October 28, 2009 Nechelik Undefined Pool CD2 -176 Well Test Program Plan 1. Drill and complete CD2 -176 with surface - controlled subsurface safety valve system according to Permit to Drill 209 -089. 2. Measure initial pressure. 3. Flowback to clean up drilling mud. 4. Tie -in to existing Drillsite CD2 manifold system with surface safety valve system. 5. Produce and commingle with other Colville River Field production at the common g p production facility. o Test >4 times /month for 1st month, then >2 test /month for 5 months. o Include in Colville River Field allocation scheme. 6. Sample and analyze oil and gas. 7. Pending outcome of production performance, stimulate CD2 -176 via hydraulic fracturing (Sundry Approval Form 10 -403 to be filed later if needed.) 8. Report after 6 month test production. Conocoillips • • RE: CD2 -176 (Permit -to -Drill 209 -098) October 28, 2009 Nechelik Undefined Pool Bcc: Jack Walker Tim Schneider Doug Knock Conoco iliips Page 1 of 1 • Schwartz, Guy L (DOA) From: Walker, Jack A [ Jack .A.Walker @conocophillips.com] Sent: Monday, November 02, 2009 2:56 PM To: Schwartz, Guy L (DOA) Cc: Anderson, Nina M; Knock, Douglas G; Roadifer, R D Subject: CD2 -176 Alpine C Sand Guy, Thanks for the call today regarding subsurface commingling of production from the Alpine and Nechelik zones in CD2 -176. I believe the Alpine zone in CD2 -176 (PTD 209 -098) is within the Alpine Oil Pool. Our pick for the top of Alpine C Sand is 7123'SSTVD, 2567FNL, 4932 FEL, Sec 27 R4E, T12N. The Alpine C Sand is approximately 20 -feet TVD thickness. We are undecided on whether we will propose downhole commingling, but we would like to complete the Alpine zone in the well to enable production of Alpine isolated from Nechelik and vice versa, or commingled production. Jack 11/2/2009 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, November 02, 2009 2:46 PM To: 'Anderson, Nina M' Cc: ' Jack.walker ©conocophillips.com' Subject: RE: CD2 -176 Single Selective Schematic (PTD 209 -098) Nina, As per our conversation I have talked to Jack and he is working the downhole commingling issue involving the Nechelik and Alpine C pools. You have approval to change the completion as shown in the new schematic which replaces the single completion with a selective single (Alpine C behind pipe). Remember, the two pools cannot be produced together until AOGCC gives formal approval and a hearing is scheduled. Thanks, Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Anderson, Nina M [mailto: Nina .Anderson @conocophillips.com] Sent: Monday, November 02, 2009 2:04 PM To: Schwartz, Guy L (DOA) Subject: CD2 -176 Single Selective Schematic Guy — Below is the proposed single selective completion for CD2 -176. This would allow selective production from the Alpine C interval through either a sliding sleeve or injection mandrel. Please let me know if you have any questions or concerns. Thanks, Nina Anderson Drilling Engineer Alpine Drilling Team Office: (907) - 265 -6403 Cell: (907) 575 -3256 11/2/2009 i Colville River Field CD2 -176 Production Well Completion I P - p z - 0 Packer Fluid mix: , Inhibited 9.2 - 9.4 ppg 6% KCI Brine ''''' 99 '` : :: , 16" Conductor to 114' with 1500' TVD diesel cap Upper Completion MD TVD N 1) Tubing Hanger 32' 32' 2) 4 -'/2" 12.6 # /ft IBT -Mod Tubing (2 jts), XO 3) 3 -'/2" 9.3 #/ft EUE -Mod Tubing 4) Camco TRMAXX -5E SSSV (2.812" ID) 2200' 1915' 0 - -= with control line to surface 5) 3- 9.3 #/ft EUE -Mod Tubing 10' < 45.5 ppf L-80 BTC Mod 6) Camco KBMG GLM w/ DV 5937' 3400' An ilk Surface Casing 7) 3 -' /2" 9.3 #/ft EUE -Mod Tubing @ 3394' MD / 2400' TVD 8) Camco KBMG GLM w/ DV 11533' 5600' cemented to surface 6 GL J 9) 3 -' /z' 9.3 #/ft EUE -Mod Tubing 10) Camco KBMG GLM (2.867" ID) w /DCK2 shear 15968' 7343' TOC @ +/ Pinned for 2500 psi casing to tbg shear 7134' MD, __ Qannik Interval 11) 3 - %" Tubing Joints EUE -Mod (1) 3870' ND Top +/- 7634' MD / 4067' TVD 12) HES 2.813" X Profile Base +/- 7850' MD / 4152' TVD 13) 3 - %" 9.3 #/ft EUE Tubing 1 jt 14) Baker Premier Packer TBD 0 O O 15) 3 - 9.3 #/ft EUE Tubing 1 jt ES Cementer 16) 3 - x 1 -'/2" Camco MMG - Injection Mandrel TBD +/- 8184' 17)3- 1 /2 "9.3 #/ft EUE Tubing 1 jt 4283' TVD 18) 3-%" 9.3 IBT with XX' blast rings & TBD 0. /26 cross coupling from XXXX' to XXXX' MD � ^ 19)3- % "9.3 #/ft EUE Tubing " \ 20) Baker "X" CMD Sliding Sleeve 2.813" /� 21) 3-%" Tubing Joints EUE -Mod (1) � 1 � V 22) Baker Premier Packer TBD 1 '/2 23) 3 -' tubing 1 joint 8 GL J ` 24) HES XN 2.813" (2.75" NoGo)- 16118' 7402' f with RHC Plug 3 -1/2" 9.3 ppf L -80 EUE M 25) 3 -1/2" Tubing Joints EUE -Mod tubing run with Jet Lube Run'n'Seal 26) BOT Stinger w /Fluted WLEG stinger 16168' 7422' pipe dope Lower Completion: Top MD TVD 27) Baker 5 -1/2" x 7 -5/8" Flexlock Liner Hanger Assembly (500' up from 7 -5/8" Shoe) 16165' 7421' X/O 5 -'/2' Hydril 521 Box x 4 -%" SLHT Pin 28) 4 - Blank Liner w /Perforate Pups w/ SLHT TBD 1 Perf Pup every 5 joints X/O 4 - SLHT Box x 4 - IBT -Mod 29) 4 - Blank Liner w /Perforate Pups w/ IBT -Mod TBD 0 ' v 1 Perf Pup every 5 joints 30) Orange Peel Shoe 23591' 7512' kAv4 � \ 14 NOTE: If T &D numbers indicate liner rotation maybe / needed, the plan will be to run +1- 2000' 4 -Y2" 12.6 #/ft TOC Calculated I f SLHT with pre - drilled pups and +7- 4000' 4 -Y2" IBTM with @ +/- 15,000' MD / 6963' pert pups. (similar to CD3 - 115). .i (300' above Packer & 500' ML /' ' ° ~ _ _ __ above Kuparuk) � /�'® ® so o0 00 00 00 00 0 0 D 0 D O 0 0 0 u Top Kuparuk C 15,472' MD / 7149' ND ® i 0 0 IV uGG""" Top Alpine C /UJU /Alpine A 15,589' MD / 7195' ND Top Nechelik 16404' MD / 7502' TVD 7 -5/8" 29.7 ppf L -80 BTC Mod 6-% Hole TD at Production Casing @ 16,784' MD / 7572' TVD at 23,591' MD / 7512' TVD Updated 10/15/2009 Sperry Drilling Services CD2- 176wp04 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, November 02, 2009 8:12 AM To: 'Anderson, Nina M'; Maunder, Thomas E (DOA) Cc: Chambers, Mark A; Alvord, Chip; Noel, Brian Subject: CD2 -176 (PTD 209 -098) Nina, Do you have a current update for Monday morning? Did the Kuparuk C sand have any show here. Don't' think we were expecting any reservoir here though. Give me a call when you can this morning. How close are you to casing depth? Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Anderson, Nina M [mailto: Nina .Anderson @conocophillips.com] Sent: Saturday, October 31, 2009 1:30 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: Chambers, Mark A; Alvord, Chip; Noel, Brian Subject: Tom / Guy - Doyon 19 encountered 20' of good reservoir quality unswept Alpine C sand on Friday October 30th while drilling the intermediate section. The well was shut -in at 13:18 hrs at 15,662' MD after taking a kick while drilling with 10.5 ppg EMW. The pressure through the Kuparuk and Alpine sands was anticipated to be 10.5 ppg EMW and the mud system had been weighted up from 9.8 ppg to 10.5 ppg prior to entering the HRZ. The initial SIDPP was 270 psi and the initial SICP was 330 psi. Following a circulation to surface, the SIDPP was 260 psi and the SICP was 230 psi for a calculated KWM of 11.2 ppg. The mud system was weighted up to 11.2 ppg throughout the evening and ECD's were monitored with Sperry's PWD. By Saturday morning October 31st, the circulated mud system was 11.2 ppg with pump rates at 8.5 bpm, ECD's at 11.8 ppg with no losses, and the pipe rotating freely at 20 - 30 rpm. The well conditions were not gaining nor losing mud at these parameters, although gas was still bubbling through to surface. Currently at 1200 hrs Doyon 19 is weighting the mud system from 11.2 to 11.5 ppg EMW. An Alpine C sand gas injector to the south has been SI as of 10:00 hrs on Saturday. The current plan forward is to circulate 11.5 ppg EMW to surface and monitor the well. If conditions are stable, drilling will continue to the planned TD of 16,404' MD landing in the Necheiik reservoir. Once at surface, the BOPE will be tested. The company man on Doyon 19 notified the AOGCC slope inspectors after the well was SI and has continued to provide updates throughout the weekend. Please contact me if you have any further questions or concerns, Thanks Nina Anderson Alpine Drilling Engineer 265 -6403 (office) 575 -3256 (cell) 11/2/2009 • • Page 1 of 2 Regg, James B (DOA) 7-C1 -Cq From: Doyon 19 Company Man [doyon1 @conocophillips.com] 0 Li C9 Sent: Sunday, November 01, 2009 12:23 PM 61/6 To: DOA AOGCC Prudhoe Bay C Cc: Anderson, Nina M; Chambers, Mark A Subject: Well Control Incident CD2 -176 Gentlemen here is a short break down of the well control issues we had on Doyon 19 well CD2 -176. We got back to drilling @ 0100 hrs 11 -1 -09 and are drilling ahead at this time w/ 11.8 ppg mud. Initially the well was shut in with the upper pipe rams and later we switched to the annular to facilitate pipe movement during this operation. We will test the equipment used on the next trip out of the hole. If I have left out anything or you need more info please give me a call. We were on bottom drilling ahead w/ 10.5 ppg mud when the pump pressure decreased from 3830 psi to 3770 psi and an increase in flow was detected. Picked up off bottom from 15662' (7228' TVD) to 15650'. Monitor well while pumping 725 gpm w/ 3770 psi. At this time the pit volume increased. Shut in well @ 1319 hrs. Notified town drilling engineer, drilling manager, pad operator, and AOGCC of well control incident. Shut in pressures were SIDP 270 psi, SICP 300 psi. Circulate through choke begin losing returns stop and shut in well, monitor pressures (SIDP 270, SICP 300).Resume pumping and regain full returns. Circulated surface to surface= (14000 strokes). Maintain 11.48 ECD's. Shut down and monitor well f/ 30 minutes. Initial drill pipe pressure 190 psi; after 15 minutes, stable at 260 psi, stayed 260 psi. Initial csg pressure 210 psi, final 230 psi. Kill wt mud appears to be 11.3 ppg. Circulate and weight up from 10.5 ppg to 10.8 ppg while circulating through the choke. Maintain 11.48 to 11.52 equivalent mud weight w/ Sperry Sun PWD tools. Pumping 65 to 66 spm (275 to 277 gpm) w/ 980 to 1010 psi. Final 65 spm (273 gpm) w/ 910 psi on drill pipe, 20 psi on csg. Mud weight is 10.8 ppg to surface at midnight (10- 30-09). Shut down and monitor well f/ 30 minutes. Initial drill pipe pressure 60 psi; after 15 minutes, stable at 120 psi, stayed 120 psi. Initial csg pressure 60 psi, final 150 psi. Kill wt mud appears to be 11.2 to 11.3 ppg. Circulate and weight up from 10.8 ppg to 11.2 ppg while circulating through the choke. Maintain 11.48 to 11.52 equivalent mud weight w/ Sperry Sun PWD tools. Pumping 65 to 66 spm (275 to 277 gpm) w/ 920 to 930 psi w/ wide open choke at almost surface to surface. Final 66 spm (273 gpm) w/ 920 psi on drill pipe, 0 psi on csg. Mud weight @ shakers was 11.1 ppg at 0630 hrs. Monitor well: Initial and final dp pressure was 30 psi. Initial csg pressure was o, final 70 psi. Continue to circulate and weight up to 11.2 ppg, taking returns through the choke. Pumping 275 gpm w/ 920 psi - choke side open. Monitor well: Initial and final dp pressure was 30 psi. Initial and final casing pressure was 0 psi. Note: Rotate drill string with annular closed: 24k ft Ibs to break free, then 18 k ft Ibs of torque to rotate freely every 2 hours. Open choke, open annular @ 0830 hrs, rotate pipe freely w/ 17.5k ft Ibs of torque. Start circulating 315 gpm w/ 1180 psi -20% flow out - -ECD's 11.75 ppg. Rotate 50 rpm w/ 17.5k ft Ibs of torque. Continue circulating and weight up from 11.2 ppg to 11.5 ppg. Pumping 378 gpm w/ 1480 psi. Monitor well: Slight flow, gained less than a bbl. Continue to circulate 11.5 ppg mud, then weight up to 11.8 ppg. Initial circ rate of 350 gpm w/ 1350 psi- Final rate of 269 gpm w/ 1060 psi- 19% flow out - -ECD's 12.46 ppg. Rotate 70 rpm w/ 19.5k ft Ibs of torque. Obtain slow pump rates w/ 11.8 ppg mud. Monitor well: Slight losses. Circulate bottom's up pumping 378 gpm w/ 1685 psi- 23% flow out - -12.52 ppg ECD's. Adding dyna red fine and /or nut plug fine 2 sx/10 min (12 sx per hour). Fred Herbert / Granville Rizek 11/6/2009 Page 2 of 2 Doyon 19 Company Man (0) 670 -4300 Fax 670 -4301 11/6/2009 • A a @" ` f 1 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS /i 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION & ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Colville River Field, Nechelik Undefined Oil Pool, CD2 -176 ConocoPhillips Alaska, Inc. Permit No: 209 -098 Surface Location: 2217' FNL, 2063' FEL, Sec, 2m T11N R4E, UM Bottomhole Location: 1409' FNL, 4788 FEL, Sec 21, T12N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Please note that permitted well is outside of existing Nechelik Pool boundaries and therefore, cannot be produced without first obtaining surface commingling approval from the AOGCC. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Cathy • . Foerster Commissioner DATED this day of September, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ! , II STATE OF ALASKA .. E;:.;� ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Current Well Class: Exploratory ❑ evelopment Oil d� �? P 1 c. Specify if well is proposed for: Drill Q E, , Re -drill ❑ Stratigraphic Test ❑ Service ' ` W "D evelopment Gas ❑ 4 Coalbed Methane ❑ Gas Hydrates ❑ Re -entry El Multiple Zone L.... Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: U Blanket LJ Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 CD2 - 176 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 i MD: 23855' • TVD: 7512' ' Colville River Field 4a. Location of Well (Governmental Section): 7. Property Designation: ADL 38000 �(� Q q N �GF�Q ( U3 I"I )ld Surface: 2217 FNL, 2063 FEL, Sec 2, T11 N, R4E, UM • ADL 387212, 387211, 02 AskCNPaAO1 /r i' AI n/ r Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4 1651 FNL, 386 FEL, Sec 28, T12N, R4E, UM 380075 9/20/2009 ,�/ Total Depth: 9. Acres in Property: 14. Distance to >2 ∎ `�` a 1409 FNL, 4788 FEL, Sec 21, T12N, R4E, UM 2560 A / 4. Cq Nearest Property: - mi - ' e PA ' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 5/, 7,...3.71e 15. Distance to yearest Well Open t0 Surface: x - 371170 • y - 5974149 • Zone 4 KB Elevation above GL:36 , 51.9 feet same �o. . CD2 - - = i I B 16. Deviated wells: Kickoff depth: 250 • ft. 17. Maximum Anticipated Pressures in psig (see 20 ' ' C 25.035) T Maximum Hole Angle: 90° deg Downhole: 3398 psig . Surface: 2646 psig • 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 77 37 37 114 114 Pre - installed 13.5" 10.75" 45.5# L -80 BTC -M 3357 37 37 3394 2400 608 sx ASL3, 270 sx 15.8 cl G 9.875" 7.625" 29.7# L -80 BTC -M 16747 37 37 16784 7572 475 sx 15.8 cl G, 270 sx cl G for K2 6.75" 3.5 9.3# L -80 EUE -M 16136 32 32 16168 7422 Production tubing 4.5 12.6# L -80 BTCM 8343 15512 6932 23855 7512 Liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch ❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis 0 Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Nina Anderson @ 265 - 6403 � 09_0_09 Printed Name G. L. Alvord Title Alaska Drilling Manager P(1 Signature Li 4 Zi Phone � ^, 3, g Date "_ o ff 444 w � infrf 3 -- ,i9A &Ay/4vgja Commission Use Only Permit to Drill API Number: Permit Appr al See cover letter Number: 2_i �� ' / O9 50 - /C.) 766C3 eC) I Date: q�x p f for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed m t ane, gas hydrates, or gas contained in shales: 2 Jf 3 S o pct u o I 7S Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No [/ Other: lcS H2S measures: Yes ❑ No 2- Directional svy req'd: Yes L " No ❑ d b Pte.. /"^ k t r. /) i D ►UtrTcr Lief. ZvC✓' D re...1 -Z re.r L& Ai4C ZS.03SC")") / APP VED BY THE COMMISSION DATE: / -2_13 -DI , , COMMISSIONER Form 10 -401 (Revised 1/2009) 'f.Z •b 9 ub it in Dlic - at 61. • • CD2 -176 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13 -1/2" Hole / 10 -3/4" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots, traveling cylinder diagrams Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries 9 -7/8" Hole / 7 -5/8" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Intermediate Formations Check for flow during connections and if needed, increase mud weight. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur nearby the planned wellbore. Hydrogen Sulfide gas Low H drills, detection systems, alarms, standard well control practices, mud scavengers 6 -3/4" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7 -5/8" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. Hydrogen Sulfide gas Low H drills, detection systems, alarms, standard well control practices, mud scavengers Q RIGINAL • • Fiord Nechelik : CD2 -176 Procedure 1) Move on Doyon 19, dewater ellar as needed. 2) Rig up riser. ( iv/ 3) Drill 13 -1/2" hole to the surface casing point as per the directional plan. (Directional /MWD). 4) Run and cement 10 -3/4" surface casing. 5) Install and test BOPE to 3500 psi. 6) Pressure test casing to 2500 psi. 7) Drill out 20' of new hole. Perform leak off test. 8) Pick up and run in hole with 9 -7/8" drilling BHA. 9) Drill 9 -7/8" hole to intermediate casing point in the reservoir sand. (LWD Program: GR /RES /PWD) 10) Run and cement 7 -5/8" casing as per program. Pressure test casing to 3500 psi. Carry out a leak off test down the 9 -5/8" x 7 -5/8" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 11) BOPE test to 3500 psi. 12) Drill out 9 -7/8" shoe track. Drill 20' of new hole. Perform formation integrity test. 13) Displace well to FIo -Thru drilling fluid. 14) Drill 6 -3/4" horizontal section to well TD (LWD Program: GR /RES /PWD /Dens /Neut). 15) Circulate the hole clean and pull out of hole. 16) Run lower completion of 4 -1/2" perforated liner and liner hanger. 17) Run upper completion: 3 -V2, 9.3 #, L -80 tubing with SSSV, gas lift mandrels, packer, landing nipple and wireline entry guide. Sting in, space out, and land hanger. 18) Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 19) Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 20) Circulate tubing to diesel and install freeze protection in the annulus. 21) Drop ball and rod, set packer and test tubing and annulus to 3500 psi for 30 mins. 22) Set BPV and secure well. Move rig off. nPirINti,1 • • Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2 -75 is the closest existing well. Ellipse to ellipse separation is 12' @ 449' MD. Drilling Area Risks: There are no high -risk events (e.g. over - pressures zones) anticipated. Lost circulation: Faulting within the Nechelik reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD2 -176 will be injected into a permitted annulus on CD2 pad or the class 2 /Class 1 disposal well on CD1 pad. The CD2 -176 surface /intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Nechelik reservoir, potential Kuparuk reservoir and the Qannik reservoir. There will be 500' of cement fill above the top of the Kuparuk reservoir along with 500' above and below the Qannik reservoir per regulations. Upon completion of CD2 -176 form 10 -403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable /industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C -40). These 450 -500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2997 psi Pore Pressure = 1,086 psi Therefore Differential = 2997 — 1086 = 1911 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10 -3/4" 45.5 L -80 3 BTC -M 2480 2108 psi 3580 psi 3043 psi 7 -5/8" 29.7 L -80 3 BTC -M 4790 psi 4071 psi 6890 psi 5856 psi • • DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7 - Production Hole 10 -3/4 "surface casing 5/8 casing point — 9 -7/8" Section — 6 3/4" point— 13 -1/2" Density 8.8 — 9.6 ppg 9.6 —10.6 ppg 9.2 ppg PV 10 — 25 10 —15 YP 20 -60 15 -25 25 -30 Funnel Viscosity 100 — 200 Initial Gels 4 — 8 10 —15 10 minute gels <18 12 - 20 API Filtrate NC — 10 cc / 30 min 4 —12 cc /30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc /30 min PH 8.5 -9.0 9.0 -10.0 9.0 -9.5 KCL 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec /qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a M -I Flo -Thru drill -in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo -Vis Polymer and Dual -Flo starch will be used for viscosity and fluid loss control respectively. onirli A 0 • Colville River Field CD2 -176 Production Well Completion "" , Updated 09/10/2009 ' 16 Conductor to 114' Sperry Drilling Services ' - CD2- 176wp03 pm i, Packer Fluid mix: ililililili 4 Inhibited 9.2 - 9.4 pin 6% KCI Brine with 1500' TVD diesel cap is 10-W 45.5 ppf L -80 BTC -Mod Surface Casing @ 3394' MD / 2400' TVD GL J cemented to surface Upper Completion MD TVD TOC © +/ 7134' MD/ mm Qannik Interval 1) Tubing Hanger 32' 32' 3870' ND 1111111 Top +/- 7634' MD / 4067 TVD 2) 4 -' /2" 12.6#/ft IBT -Mod Tubing (2 jts), XO III Base +/- 7850' MD / 4152' TVD 3) 3 -'W 9.3 #/ft EUE -Mod Tubing 4) Camco TRMAXX -5E SSSV (2.812" ID) 2200' 1915' with control line to surface '° ES Cementer 5) 3 -' /2' 9.3 #/ft EUE -Mod Tubing +/- 8184' MD / 6) Camco KBMG GLM w/ DV 5937' 3400' 4283' TVD - 7) 3-W 9.3 #/ft EUE -Mod Tubing 8) Camco KBMG GLM w/ DV 11533' 5600' 9) 3-W 9.3 #/ft EUE -Mod Tubing 10) Camco KBMG GLM (2.867" ID) w /DCK2 shear 15968' 7343' Pinned for 2500 psi casing to tbg shear 11) 3 -' /2' 9.3#/ft, EUE -M (2) 12) Baker 3.5" X 7 -5/8" Premier Packer 16068' 7383' O pt; J 13) 3 -' /2' 9.3#/ft, EUE -M (1) 14) HES "XN" (2.75" min ID) @ 66 16118' 7402' 15) 3'/2'9.3# /ft, EUE -M 3 -1/2" 9.3 ppf L -80 EUE M 16) 3- 9.3 # /ft, EUE -M w/ mule shoe located at 16168' 7422' tubing run with Jet Lube Run'n'Seal WLEG sub bottom, +/15513' pipe dope Lower Completion: Too MD TVD 17) Baker 5" x 7" Flexlock Liner Hanger 15512' 6932' 18) 4-W, Blank Linerw /Perforate Pups IBTM 1 perf pup every 5 joints 19) Orange Peel Shoe 23855' 7512' NOTE: If T &D numbers indicate liner rotation may be needed, the plan will be to run +/- 2000' 445" 12.6 #/ft C Calculated SLHT with pre - drilled pups and +/- 4000' 4 -1h" 1BTM with 15,000' MD 1 6963' TVL? :: /©°+/- 00' abo e perf pups. (similar fo CD3 -115). v Packer & 500' MD ": above Kuparuk) ''® 0 0 Cr? 0 OO °O °° °° O° 00 1 O o O° Top Kuparuk C 15,501' MD / 7159' TVD 0 Top Alpine C /UJU /Alpine A 15,656' MD / 7220' TVD " "' 1 11 , .,,, ,, Top Nechelik 16502' MD / 7527' TVD 6'/4" Hole TD at 7 -5/8" 29.7 ppf L -80 BTC Mod at 23,855' MD / 7512' TVD Production Casing @ 16,784' MD / 7572' TVD ORGtNA CD2 -176 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (Ibs. / gal) (psi) (psi) 16 114 / 114 10.9 52 53 10 -3/4 3394 / 2400 14.5 1086 1569 7 -5/8 16784 / 7572 16.0 3425 2646 N/A 23855 / 7512 16.0 3398 N/A • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi /ft 0.1 = Gas gradient in psi /ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP — (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16 ") ASP = [(FG x 0.052) — 0.1] D = [(10.9 x 0.052) — 0.1] x 114 = 53 psi OR ASP = FPP — (0.1 x D) = 1086 — (0.1 x 2400') = 846 psi 2. Drilling below surface casing (10 3/4 ") ASP = [(FG x 0.052) — 0.1] D = [(14.5 x 0.052) — 0.1] x 2400 = 1569 psi OR ASP = FPP — (0.1 x D) = 3425 — (0.1 x7572') = 2668 psi 3. Drilling below intermediate casing (7 -5/8 ") ASP = FPP — (0.1 x D) = 3398 — (0.1 x 7512') = 2646 psi OR IGINAL • Cementing Program: 10 -3/4" Surface Casing run to 3394' MD / 2400' TVD. Cement from 3394' MD to 2894' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2894' to surface with Arctic Set Lite 3. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1555' MD). Lead slurry: (2894'- 1550') X 0.3637 ft /ft X 1.5 (50% excess) = 733.22 ft below permafrost 1550' X 0.3637 ft /ft X 3.5 (250% excess) = 1973.1 ft above permafrost Total volume = 733.22 + 1973.1 = 2706.3 ft => 608 Sx @ 4.45 ft /sk System: 608 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft /sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW' D044 freeze suppressant Tail slurry: 500' X 0.3637 ft /ft X 1.5 (50% excess) = 272.8 ft annular volume 80' X 0.5397 ft /ft = 43.2 ft shoe joint volume Total volume = 272.8 + 43.2 = 316 ft => 270 Sx @ 1.17 ft /sk System: 270 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft /sk 7 -5/8" Intermediate Casing run to 16784' MD / 7572' TVD: Cemented in two stages Cement from 16,784' MD to 15,000' MD (300' MD above the packer & 500' MD above top of Kuparuk reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. First Stage: Lead: (16784' - 15000') X 0.2146 ft /ft X 1.4 (40% excess) = 536 ft annular vol. 80' X 0.2577 ft /ft = 20.6 ft shoe joint volume Total volume = 536 + 20.6 = 556.6 ft => 475 Sx @ 1.17 ft /sk System: 475 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.17 ft /sk Second Stage: Cement from ports in a stage tool set 500' below the Qannik (K2) interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (8184' - 7134') X 0.2146 ft /ft X 1.4 (40% excess) = 315 ft annular vol. Total Volume = 315 ft => 270 Sk @ 1.17 ft /sk System: 270 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.17 ft /sk 1 By Weight Of mix Water, all other additives are BWOCemnt fl • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 4/18/07 CZ DB C.A. ISSUED PER K07041ACS 2 4/21/08 CZ GD C.A. UPDATED PER K080010ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.2, T 11 N, R 4 E, U.M. SEC.LINE 0/S EXIST WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD 002 -461 5,973,927.48 1,511,501.61 70' 20' 4.465" 151' 02' 45.814" 3099' 1765' 8.3 15.7 CO2 -462 5,973,925.28 1,511,481.66 70' 20' 4.440" 151' 02' 46.395" 3096' 1785' 8.3 15.7 CO2 -463 5,973,923.32 1,511,461.85 70' 20' 4.417" 151° 02' 46.973" 3094' 1805' 8.3 15.7 002 -464 5,973,921.12 1,511,442.08 70' 20' 4.392" 151' 02' 47.549" 3091' 1825' 8.3 15.7 CO2 -465 5,973,919.18 1,511,422.01 70° 20' 4.370" 151° 02' 48.134" 3089' 1845' 7.8 15.7 002 -466 5,973,916.76 1,511,402.40 70' 20' 4.343" 151' 02' 48.706" 3086' 1864' 7.8 15.7 CO2 -467 5,973,915.01 1,511,382.20 70' 20' 4.322" 151° 02' 49.295" 3084' 1884' 7.9 15.7 CD2 -468 5,973,912.62 , 1,511,362.41 70' 20' 4.295" 151' 02' 49.872" 3081' 1904' 7.9 15.6 002 -469 5,973,910.54 1,511,342.61 70' 20' 4.271" 151° 02' 50.449" 3079' 1924' 8.0 15.6 002 -470 5,973,908.62 1,511,322.72 70' 20' 4.249" 151' 02' 51.029" 3077' 1944' 8.0 15.6 002 -471 5,973,906.37 1,511,302.77 70' 20' 4.224" 151° 02' 51.610" 3074' 1964' 8.1 15.6 002 -72 5,973,904.22 1,511,282.90 70' 20' 4.199" 151' 02' 52.189" 3072' 1984' 8.1 15.6 002 -73 5,973,902.15 1,511,262.95 _ 70' 20' 4.175" 151° 02' 52.771" 3069' 2003' 8.2 15.6 002 -74 5,973,899.86 1,511,243.06 70' 20' 4.150" 151' 02' 53.351" 3067' 2023' 8.3 15.6 002 -75 5,973,897.83 1,511,223.26 70° 20' 4.126" 151° 02' 53.928" _ 3064' 2043' 8.4 15.6 CO2 -x76 5,793,895.84 1,511,203.39 70' 20' 4.103" 151' 02' 54.507" 3062' 2063' 8.4 15.6 CO2 -x77 5,973,893.62 1,511,183.28 _ 70' 20' 4.078" 151° 02' 55.094" 3059' 2083' 8.4 15.6 CD2 -x78 5,973,891.66 1,511,163.81 70' 20' 4.055" 151' 02 55.661" 3057' 2103' 8.4 15.6 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) KUUKPIK (-- LCMF mcewr..ns.warreo «„a„w Alpine Surve Office ALPINE MODULE:CD20 UNIT: QNK Conoc.Phillips ALPINE PROJECT QANNIK WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: R PART REV: 07- 02 -18 -1 4/2/07 �: cr > IDTr 9 2 OF 3 2 • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 4/18/07 CZ DB C.A. ISSUED PER K07041ACS 2 4/21/08 CZ GD C.A. UPDATED PER K080010ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE QANNIK GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE TO CD -5 ROAD MONUMENTS PER SURVEY BY KUUKPIK /LCMF, APRIL 2007. 4. DATES OF AS -BUILT SURVEYS: WELL CONDUCTORS CD2 -461, CD2 -462, CD2 -463, CD2 -464, 3/30/07, FB 2007 -08 PGS. 2 -3; CD2 -465, CD2 -466, CD2 -467, CD2 -468, CD2 -469, CD2 -470, CD2 -471 & CD2 -72, 4/16/07, LCMF2007 -09, PGS. 22 -24; CD2 -73, CD2 -74, CD2 -75, CD2 -x76, CD2 -x77 & CD2 -x78, 4/20/08, FB 2008 -8, PGS 72 -75. SURVEYOR'S CERTIFICATE ` I HEREBY 4 OF AL TO PRACTICE D REGISTERED ALASKA, THAT THIS 401. \ P ^ Sir ♦ AS —BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT � G ' ; •' •••• � SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST i �� ••' ♦ AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE * • j • 49th � * ; CORRECT. • 0 DATE: REGISTRATION NO. LS -5077 • • • • Donald G. Bruce o ; •0 . s � • N o . LS -5077 te a i • • F9 Fa ' • ••• ............... y, KU U KP I K 11/#441'0FESs NN- ,110. L CMF LLC tsse.sta�aa �non..o.ww (am) Alpine OfIke Alpine Survey Office 110V ALPINE MODULE:CD20 UNIT: CD CenocePh1IIIps ALPINE PROJECT QANNIK WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 07- 02 -18 -1 4/2/07 CE —CD20 -139 3 OF 3 2 r 1 1 \1A 1 'Lql 111111 ConocoPhilli s Alaska III III p � ) Inc. l u, 111 Western North Slope CD2 Alpine Pad Plan: CD2 -176 ,,1 11 Plan: CD2 -176 Plan: CD2- 176wp03 Ill'll� I' hu l il'' Standard Proposal Report A ul, II ulll D 7 10 September, 2009 l I VI S - i HALLIBURTONI Sperry Grilling Services jr. l Illl ORIGINAL • 11 Western North Slope HALLIBURTON 1.- CD2 Alpine Pad CD2-176wp03 Conoco Phillips Plan: CD2-176 Sperry Drilling Plan: CD2-176 CD2-176wp03 DDI: 6.930 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 1000.00 CD2-176wp03 (Plan: CD2-176) CB-GYRO-SS 1000.00 23855.53 CD2-176wp03 (Plan: CD2-176) MWD+IFR-AK-CAZ-SC 1 16500 , , _ _ _ CD2-176wp03 Toe "E S , r 60 o Lo P-11000 1 ..\. CD2-176wp03 Heel -1 0 z — 1 5500 = 0 :n A \\ a rA 0 I I I -22000 -16500 -11000 -5500 0 5500 11000 West(-)/East(+) (5500 ft/in) CASING DETAILS TVD MD Name Size 2400.00 3393.89 10-3/4" x 13-1/2" 10-3/4 7571.90 16783.94 7-5/8" X 9-7/8" 7-5/8 g 7511.90 23855.53 4-1/2" x 6-3/4" 4-1/2 c 0 0 ° S 10; 0 -LCIL LO 06 . -c C-20 0-3500— K-3 Market Basal K- mob, --i _ _ - ......ss....._ o 0 0 7 Basal K-2 K-2 Marker 1 . ) 5 tbl■ 0 Albian 97- -04 *=, a) ' ai Albian 96 ----I -a > 0.) HRZ Base AR; K-1 MarkeiKiiparlik DiKuparuk c:_LGU - Alpine D .-- \ .......,.., a) 7000 -L = L __-_--_- -= 1-_=.--=-1--- CD - .- 2 .- - - = _______ __AI Nibs_ -.. . - .--- F— ,— --__ Alpine C /gr Nechelik: - - - = - - - _ — - -- - — UJU CO CO _ Base iqsu u t Ba CD2-176wp03 Heel se Alpine Alpine A Sand ' CD2-176wp03 Toe 1 Nuti cpu I 1 I 1 i 0 3500 7000 10500 14000 17500 21000 ,,, __ -± Veritatinitf ar1170 ' V -- _ PP MIN AL .,-' 's • ConocoPhillips HALL1BURTON Standard Proposal Report Database: EDM v16 Prod Local Ca- ordinate Reference: Well Plan: CD2 -176 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD2 -176 (36.3 +15.6) @ 51.90ft (Doyon 19 Project 'Western North Slope MD Reference: Plan: CD2 -176 (36.3 +15.6) @ 51.90ft ( Doyon 19 Site: CD2 Alpine Pad North Reference: ' True Welk Plan: CD2 -176 Survey Calculation Method; Minimum Curvature ' Wellbore: Plan: CD2 -176 Design: CD2 176wp03 [Planned Survey , 11111 Measured - ..Vertical 1 == Map Map i, III Depth Inclination Azimuth Depth. TVDss +Nf-S +E!-W Northing Easttng= , !1' P Vert Section (ft) (°) (°j (ft) ft ( ft) ( ft ) ( ft ) - (ft) -15.60 36.30 0.00 0.00 36.30 -15.60 0.00 0.00 5,974,149.15 371,170.64 0.00 0.00 100.00 0.00 0.00 100.00 48.10 0.00 0.00 5,974,149.15 371,170.64 0.00 0.00 200.00 0.00 0.00 200.00 148.10 0.00 0.00 5,974,149.15 371,170.64 0.00 0.00 250.00 0.00 0.00 250.00 198.10 0.00 0.00 5,974,149.15 371,170.64 0.00 0.00 Start Build 1.50 300.00 0.75 340.00 300.00 248.10 0.31 -0.11 5,974,149.46 371,170.53 1.50 0.31 400.00 2.25 340.00 399.96 348.06 2.77 -1.01 5,974,151.93 371,169.68 1.50 2.78 425.06 2.63 340.00 425.00 373.10 3.77 -1.37 5,974,152.94 371,169.33 1.50 3.79 Start DLS 2.50 TFO - 5.00 500.00 4.50 337.92 499.79 447.89 8.10 -3.06 5,974,157.30 371,167.72 2.50 8.21 600.00 6.99 336.87 599.28 547.38 17.33 -6.93 5,974,166.60 371,164.01 2.50 17.81 700.00 9.49 336.37 698.24 646.34 30.49 -12.63 5,974,179.85 371,158.54 2.50 31.60 800.00 11.99 336.08 796.48 744.58 47.54 -20.14 5,974,197.03 371,151.32 2.50 49.56 803.60 12.08 336.07 800.00 748.10 48.23 -20.45 5,974,197.72 371,151.03 2.50 50.29 Start Build 3.00 900.00 14.97 336.07 893.72 841.82 68.84 -29.59 5,974,218.48 371,142.24 3.00 72.03 1,000.00 17.97 336.07 989.60 937.70 94.76 -41.09 5,974,244.59 371,131.19 3.00 99.38 1,100.00 20.97 336.07 1,083.87 1,031.97 125.23 -54.61 5,974,275.28 371,118.20 3.00 131.53 1,103.60 21.08 336.07 1,087.23 1,035.33 126.41 -55.13 5,974,276.47 371,117.69 3.00 132.78 Start DLS 3.50 TFO - 19.26 1,200.00 24.29 333.37 1,176.16 1,124.26 159.99 -71.06 5,974,310.32 371,102.35 3.50 168.86 1,300.00 27.66 331.20 1,266.05 1,214.15 198.73 -91.46 5,974,349.40 371,082.61 3.50 211.77 1,400.00 31.06 329.46 1,353.20 1,301.30 241.30 - 115.76 5,974,392.38 371,059.05 3.50 260.11 1,500.00 34.47 328.04 1,437.28 1,385.38 287.54 - 143.85 5,974,439.09 371,031.76 3.50 313.69 1,600.00 37.90 326.85 1,517.98 1,466.08 337.28 - 175.63 5,974,489.37 371,000.84 3.50 372.32 1,700.00 41.34 325.83 1,595.00 1,543.10 390.33 - 210.99 5,974,543.02 370,966.41 3.50 435.78 1,800.00 44.78 324.94 1,668.05 1,616.15 446.50 - 249.78 5,974,599.84 370,928.58 3.50 503.82 1,900.00 48.24 324.15 1,736.86 1,684.96 505.58 - 291.88 5,974,659.63 370,887.52 3.50 576.20 2,000.00 51.69 323.44 1,801.18 1,749.28 567.34 - 337.11 5,974,722.15 370,843.36 3.50 652.65 2,100.00 55.16 322.79 1,860.75 1,808.85 631.56 - 385.31 5,974,787.18 370,796.27 3.50 732.88 2,200.00 58.62 322.20 1,915.37 1,863.47 697.99 - 436.30 5,974,854.48 370,746.43 3.50 816.59 2,300.00 62.09 321.65 1,964.83 1,912.93 766.40 - 489.89 5,974,923.79 370,694.03 3.50 903.47 2,400.00 65.56 321.14 2,008.94 1,957.04 836.51 - 545.89 5,974,994.85 370,639.25 3.50 993.19 2,437.36 66.85 320.95 2,024.01 1,972.11 863.10 - 567.38 5,975,021.80 370,618.22 3.50 1,027.38 2,437.39 66.85 320.95 2,024.02 1,972.12 863.11 - 567.39 5,975,021.81 370,618.20 0.00 1,027.40 Start 13741.50 hold at 2437.39 MD 2,500.00 66.85 320.95 2,048.63 1,996.73 907.82 -603.66 5,975,067.14 370,582.71 0.00 1,084.97 2,600.00 66.85 320.95 2,087.94 2,036.04 979.23 - 661.59 5,975,139.53 370,526.02 0.00 1,176.92 2,700.00 66.85 320.95 2,127.25 2,075.35 1,050.64 - 719.52 5,975,211.91 370,469.33 0.00 1,268.87 2,800.00 66.85 320.95 2,166.55 2,114.65 1,122.05 - 777.45 5,975,284.30 370,412.65 0.00 1,360.82 2,900.00 66.85 320.95 2,205.86 2,153.96 1,193.46 - 835.38 5,975,356.69 370,355.96 0.00 1,452.77 3,000.00 66.85 320.95 2,245.17 2,193.27 1,264.87 - 893.30 5,975,429.08 370,299.27 0.00 1,544.72 3,100.00 66.85 320.95 2,284.47 2,232.57 1,336.28 - 951.23 5,975,501.47 370,242.58 0.00 1,636.68 3,200.00 66.85 320.95 2,323.78 2,271.88 1,407.69 - 1,009.16 5,975,573.86 370,185.90 0.00 1,728.63 3,300.00 66.85 320.95 2,363.09 2,311.19 1,479.10 - 1,067.09 5,975,646.24 370,129.21 0.00 1,820.58 9/10/2009 9.56:03AM Page 3 COMPASS 2003.16 Build 69 - I i L 0 ConocoPhillips HALL1BUR TON Standard Proposal Report Database: EDMv16 Prod Local Co-ordinate Reference: Well Plan: CD2 -176 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD2 -176 (36.3 +15.6) @ 51.90ft (Doyon 19 Project Western North Slope MD Reference: Plan: CD2 -176 (36.3 +15.6) @ 51.90ft (Doyon 19 Site: CD2 Alpine Pad North Reference: True Well: Plan: CD2 -176 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD2 -176 Design: 11 CD2- 176wp03 Planned Survey Measured' = Vertical Map 11 Map 1, p 1P Depth inclination Azimuth Depth TVDas +Ni-S = +E/ -W Northing Eastng DLS 11 Vert Section ( = i ° ) O (f f (ft) (ft) 11 ( ft ) (ft)` 3,30.10 3,393.91 66.85 320.95 2,400.00 2,348.10 1,546.16 - 1,121.49 5,975,714.22 370,075.97 0.00 1,906.92 10414'' x 13-1/2" 3,400.00 66.85 320.95 2,402.39 2,350.49 1,550.51 - 1,125.01 5,975,718.63 370,072.52 0.00 1,912.53 3,411.46 66.85 320.95 2,406.90 2,355.00 1,558.70 - 1,131.65 5,975,726.93 370,066.02 0.00 1,923.07 C 3,500.00 66.85 320.95 2,441.70 2,389.80 1,621.92 - 1,182.94 5,975,791.02 370,015.83 0.00 2,004.48 3,600.00 66.85 320.95 2,481.01 2,429.11 1,693.33 - 1,240.87 5,975,863.41 369,959.14 0.00 2,096.43 3,700.00 66.85 320.95 2,520.32 2,468.42 1,764.74 - 1,298.80 5,975,935.80 369,902.46 0.00 2,188.38 3,800.00 66.85 320.95 2,559.62 2,507.72 1,836.15 - 1,356.73 5,976,008.19 369,845.77 0.00 2,280.33 3,900.00 66.85 320.95 2,598.93 2,547.03 1,907.56 - 1,414.65 5,976,080.57 369,789.08 0.00 2,372.28 4,000.00 66.85 320.95 2,638.24 2,586.34 1,978.97 - 1,472.58 5,976,152.96 369,732.39 0.00 2,464.23 4,100.00 66.85 320.95 2,677.54 2,625.64 2,050.38 - 1,530.51 5,976,225.35 369,675.70 0.00 2,556.18 4,200.00 66.85 320.95 2,716.85 2,664.95 2,121.79 - 1,588.44 5,976,297.74 369,619.02 0.00 2,648.13 4,300.00 66.85 320.95 2,756.16 2,704.26 2,193.20 - 1,646.37 5,976,370.13 369,562.33 0.00 2,740.08 4,352.77 66.85 320.95 2,776.90 2,725.00 2,230.88 - 1,676.93 5,976,408.33 369,532.41 0.00 2,788.60 C - 20 4,400.00 66.85 320.95 2,795.46 2,743.56 2,264.61 - 1,704.29 5,976,442.52 369,505.64 0.00 2,832.03 4,500.00 66.85 320.95 2,834.77 2,782.87 2,336.02 - 1,762.22 5,976,514.90 369,448.95 0.00 2,923.98 4,600.00 66.85 320.95 2,874.08 2,822.18 2,407.43 - 1,820.15 5,976,587.29 369,392.27 0.00 3,015.93 4,700.00 66.85 320.95 2,913.39 2,861.49 2,478.84 - 1,878.08 5,976,659.68 369,335.58 0.00 3,107.88 4,800.00 66.85 320.95 2,952.69 2,900.79 2,550.24 - 1,936.00 5,976,732.07 369,278.89 0.00 3,199.83 4,900.00 66.85 320.95 2,992.00 2,940.10 2,621.65 - 1,993.93 5,976,804.46 369,222.20 0.00 3,291.78 5,000.00 66.85 320.95 3,031.31 2,979.41 2,693.06 - 2,051.86 5,976,876.85 369,165.51 0.00 3,383.73 5,100.00 66.85 320.95 3,070.61 3,018.71 2,764.47 - 2,109.79 5,976,949.23 369,108.83 0.00 3,475.68 5,200.00 66.85 320.95 3,109.92 3,058.02 2,835.88 - 2,167.72 5,977,021.62 369,052.14 0.00 3,567.63 , 5,300.00 66.85 320.95 3,149.23 3,097.33 2,907.29 - 2,225.64 5,977,094.01 368,995.45 0.00 3,659.58 5,400.00 66.85 320.95 3,188.53 3,136.63 2,978.70 - 2,283.57 5,977,166.40 368,938.76 0.00 3,751.53 5,500.00 66.85 320.95 3,227.84 3,175.94 3,050.11 - 2,341.50 5,977,238.79 368,882.07 0.00 3,843.48 5,600.00 66.85 320.95 3,267.15 3,215.25 3,121.52 - 2,399.43 5,977,311.18 368,825.39 0.00 3,935.43 5,700.00 66.85 320.95 3,306.46 3,254.56 3,192.93 - 2,457.36 5,977,383.56 368,768.70 0.00 4,027.38 5,800.00 66.85 320.95 3,345.76 3,293.86 3,264.34 - 2,515.28 5,977,455.95 368,712.01 0.00 4,119.33 5,900.00 66.85 320.95 3,385.07 3,333.17 3,335.75 - 2,573.21 5,977,528.34 368,655.32 0.00 4,211.28 6,000.00 66.85 320.95 3,424.38 3,372.48 3,407.16 - 2,631.14 5,977,600.73 368,598.63 0.00 4,303.24 6,100.00 66.85 320.95 3,463.68 3,411.78 3,478.57 - 2,689.07 5,977,673.12 368,541.95 0.00 4,395.19 6,200.00 66.85 320.95 3,502.99 3,451.09 3,549.98 - 2,746.99 5,977,745.51 368,485.26 0.00 4,487.14 6,300.00 66.85 320.95 3,542.30 3,490.40 3,621.39 - 2,804.92 5,977,817.90 368,428.57 0.00 4,579.09 6,400.00 66.85 320.95 3,581.60 3,529.70 3,692.80 - 2,862.85 5,977,890.28 368,371.88 0.00 4,671.04 6,500.00 66.85 320.95 3,620.91 3,569.01 3,764.21 - 2,920.78 5,977,962.67 368,315.20 0.00 4,762.99 6,600.00 66.85 320.95 3,660.22 3,608.32 3,835.62 - 2,978.71 5,978,035.06 368,258.51 0.00 4,854.94 6,700.00 66.85 320.95 3,699.53 3,647.63 3,907.03 - 3,036.63 5,978,107.45 368,201.82 0.00 4,946.89 6,800.00 66.85 320.95 3,738.83 3,686.93 3,978.44 - 3,094.56 5,978,179.84 368,145.13 0.00 5,038.84 6,900.00 66.85 320.95 3,778.14 3,726.24 4,049.85 - 3,152.49 5,978,252.23 368,088.44 0.00 5,130.79 7,000.00 66.85 320.95 3,817.45 3,765.55 4,121.25 - 3,210.42 5,978,324.61 368,031.76 0.00 5,222.74 7,069.84 66.85 320.95 3,844.90 3,793.00 4,171.13 - 3,250.88 5,978,375.17 367,992.16 0.00 5,286.96 K Marker 9/10/2009 9:56.03AM Page 4 COMPASS 2003.16 Build 69 4? ", !E� L • ConocoPhillips Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Plan: CD2 -176 Company_ !ConocoPhillips(Alaska) Inc. TVD Reference: 1 Plan: CD2 -176 (36.3 +15.6) @ 51.90ft (Doyon 19 Project: Western North Slope MD Reference: Plan: CD2 -176 (36.3 +15.6) @ 51.90ft (Doyon 19 Site: CD2 Alpine Pad North Reference: True Welt � Plan: CD2 -176 Survey Calculation Method: Minimum Curvature � Wellbore: WI Plan: CD2 -176 Design: CD2- 176wp03 n Planned Survey Measured- Vertical 1 Map Map Depth Inclination Azimuth Depth TVDss +NIS +EI-W Northing Easting . DLS Vert Section (ft) r) r) -rot) ft `` (ft) it (ft) (ft),.. 5,269.21 I 10,800.00 66.85 320.95 5,311.11 5,259.21 6,834.82 - 5,411.68 5,981,075.37 365,877.62 0.00 8,716.85 10,900.00 66.85 320.95 5,350.42 5,298.52 6,906.23 - 5,469.60 5,981,147.76 365,820.93 0.00 8,808.80 11,000.00 66.85 320.95 5,389.73 5,337.83 6,977.64 - 5,527.53 5,981,220.15 365,764.24 0.00 8,900.75 11,100.00 66.85 320.95 5,429.03 5,377.13 7,049.05 - 5,585.46 5,981,292.54 365,707.55 0.00 8,992.70 11,200.00 66.85 320.95 5,468.34 5,416.44 7,120.46 - 5,643.39 5,981,364.92 365,650.87 0.00 9,084.65 11,300.00 66.85 320.95 5,507.65 5,455.75 7,191.87 - 5,701.31 5,981,437.31 365,594.18 0.00 9,176.60 11,400.00 66.85 320.95 5,546.95 5,495.05 7,263.28 - 5,759.24 5,981,509.70 365,537.49 0.00 9,268.55 11,500.00 66.85 320.95 5,586.26 5,534.36 7,334.68 - 5,817.17 5,981,582.09 365,480.80 0.00 9,360.50 11,600.00 66.85 320.95 5,625.57 5,573.67 7,406.09 - 5,875.10 5,981,654.48 365,424.11 0.00 9,452.45 11,700.00 66.85 320.95 5,664.88 5,612.98 7,477.50 - 5,933.03 5,981,726.87 365,367.43 0.00 9,544.40 11,800.00 66.85 320.95 5,704.18 5,652.28 7,548.91 - 5,990.95 5,981,799.25 365,310.74 0.00 9,636.36 11,900.00 66.85 320.95 5,743.49 5,691.59 7,620.32 - 6,048.88 5,981,871.64 365,254.05 0.00 9,728.31 12,000.00 66.85 320.95 5,782.80 5,730.90 7,691.73 - 6,106.81 5,981,944.03 365,197.36 0.00 9,820.26 12,100.00 66.85 320.95 5,822.10 5,770.20 7,763.14 - 6,164.74 5,982,016.42 365,140.68 0.00 9,912.21 12,175.81 66.85 320.95 5,851.90 5,800.00 7,817.27 - 6,208.65 5,982,071.29 365,097.70 0.00 9,981.91 Albian 96 12,200.00 66.85 320.95 5,861.41 5,809.51 7,834.55 - 6,222.67 5,982,088.81 365,083.99 0.00 10,004.16 12,300.00 66.85 320.95 5,900.72 5,848.82 7,905.96 - 6,280.59 5,982,161.20 365,027.30 0.00 10,096.11 12,400.00 66.85 320.95 5,940.02 5,888.12 7,977.37 - 6,338.52 5,982,233.58 364,970.61 0.00 10,188.06 12,500.00 66.85 320.95 5,979.33 5,927.43 8,048.78 - 6,396.45 5,982,305.97 364,913.92 0.00 10,280.01 12,600.00 66.85 320.95 6,018.64 5,966.74 8,120.19 - 6,454.38 5,982,378.36 364,857.24 0.00 10,371.96 12,700.00 66.85 320.95 6,057.94 6,006.04 8,191.60 - 6,512.30 5,982,450.75 364,800.55 0.00 10,463.91 12,800.00 66.85 320.95 6,097.25 6,045.35 8,263.01 - 6,570.23 5,982,523.14 364,743.86 0.00 10,555.86 12,900.00 66.85 320.95 6,136.56 6,084.66 8,334.42 - 6,628.16 5,982,595.53 364,687.17 0.00 10,647.81 13,000.00 66.85 320.95 6,175.87 6,123.97 8,405.83 - 6,686.09 5,982,667.91 364,630.48 0.00 10,739.76 13,100.00 66.85 320.95 6,215.17 6,163.27 8,477.24 - 6,744.02 5,982,740.30 364,573.80 0.00 10,831.71 13,200.00 66.85 320.95 6,254.48 6,202.58 8,548.65 - 6,801.94 5,982,812.69 364,517.11 0.00 10,923.66 13,300.00 66.85 320.95 6,293.79 6,241.89 8,620.06 - 6,859.87 5,982,885.08 364,460.42 0.00 11,015.61 13,400.00 66.85 320.95 6,333.09 6,281.19 8,691.47 - 6,917.80 5,982,957.47 364,403.73 0.00 11,107.56 13,500.00 66.85 320.95 6,372.40 6,320.50 8,762.88 - 6,975.73 5,983,029.86 364,347.05 0.00 11,199.51 13,600.00 66.85 320.95 6,411.71 6,359.81 8,834.29 - 7,033.66 5,983,102.25 364,290.36 0.00 11,291.46 13,700.00 66.85 320.95 6,451.01 6,399.11 8,905.69 - 7,091.58 5,983,174.63 364,233.67 0.00 11,383.41 13,800.00 66.85 320.95 6,490.32 6,438.42 8,977.10 - 7,149.51 5,983,247.02 364,176.98 0.00 11,475.36 13,900.00 66.85 320.95 6,529.63 6,477.73 9,048.51 - 7,207.44 5,983,319.41 364,120.29 0.00 11,567.31 14,000.00 66.85 320.95 6,568.94 6,517.04 9,119.92 - 7,265.37 5,983,391.80 364,063.61 0.00 11,659.26 14,100.00 66.85 320.95 6,608.24 6,556.34 9,191.33 - 7,323.29 5,983,464.19 364,006.92 0.00 11,751.21 14,200.00 66.85 320.95 6,647.55 6,595.65 9,262.74 - 7,381.22 5,983,536.58 363,950.23 0.00 11,843.16 14,300.00 66.85 320.95 6,686.86 6,634.96 9,334.15 - 7,439.15 5,983,608.96 363,893.54 0.00 11,935.11 14,400.00 66.85 320.95 6,726.16 6,674.26 9,405.56 - 7,497.08 5,983,681.35 363,836.85 0.00 12,027.06 14,500.00 66.85 320.95 6,765.47 6,713.57 9,476.97 - 7,555.01 5,983,753.74 363,780.17 0.00 12,119.01 14,600.00 66.85 320.95 6,804.78 6,752.88 9,548.38 - 7,612.93 5,983,826.13 363,723.48 0.00 12,210.97 14,700.00 66.85 320.95 6,844.08 6,792.18 9,619.79 -7,670.86 5,983,898.52 363,666.79 0.00 12,302.92 14,800.00 66.85 320.95 6,883.39 6,831.49 9,691.20 - 7,728.79 5,983,970.91 363,610.10 0.00 12,394.87 14,821.65 66.85 320.95 6,891.90 6,840.00 9,706.66 - 7,741.33 5,983,986.57 363,597.83 0.00 12,414.77 HRZ 9/10/2009 9 :56.03AM Page 6 COMPASS 2003.16 Build 69 t1 r L ConocoPhillips Standard Proposal Report Database: EDM v16 Prod Local Co- ordinate Reference: Well Plan: CD2 -176 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Plan: CD2 -176 (36.3 +15.6) @ 51.90ft (Doyon 19 Project: Western North Slope MD Reference: Plan: CD2 -176 (36.3 +15.6) @ 51.90ft (Doyon 19 Site. = CD2 Alpine Pad North Reference:' True Well: Plan: CD2 -176 Survey Calculation Method: Minimum Curvature Wellborn: Plan: CD2 -176 Design. CD2- 176wp03 Planned Surrey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N!-S +Et -W Northing . Easting DLS 1 11, 1 Vert Sectioti ( (} (°) _ , (ft) ft (ft) (ft) (ft) 1 ) 7, 16,900.00 87.53 321.43 7,579.46 7,527.56 11,221.88 - 8,965.96 5,985,522.48 362,399.51 2.18 14,362.98 17,000.00 89.71 321.43 7,581.87 7,529.97 11,300.03 - 9,028.29 5,985,601.69 362,338.54 2.18 14,462.94 17,013.27 90.00 321.43 7,581.90 7,530.00 11,310.41 - 9,036.56 5,985,612.21 362,330.44 2.18 14,476.21 Start DLS 2.00 TFO - 0.02 17,042.64 90.59 321.43 7,581.75 7,529.85 11,333.37 - 9,054.88 5,985,635.48 362,312.53 2.00 14,505.58 Start 6812.89 hold at 17042.64 MD 17,100.00 90.59 321.43 7,581.16 7,529.26 11,378.22 - 9,090.63 5,985,680.93 362,277.56 0.00 14,562.93 I 17,200.00 90.59 321.43 7,580.14 7,528.24 11,456.40 - 9,152.97 5,985,760.17 362,216.58 0.00 14,662.91 17,300.00 90.59 321.43 7,579.11 7,527.21 11,534.59 - 9,215.31 5,985,839.41 362,155.60 0.00 14,762.90 17,400.00 90.59 321.43 7,578.09 7,526.19 11,612.77 - 9,277.64 5,985,918.65 362,094.61 0.00 14,862.89 17,500.00 90.59 321.43 7,577.06 7,525.16 11,690.96 - 9,339.98 5,985,997.89 362,033.63 0.00 14,962.88 17,600.00 90.59 321.43 7,576.04 7,524.14 11,769.15 - 9,402.32 5,986,077.13 361,972.65 0.00 15,062.86 17,700.00 90.59 321.43 7,575.01 7,523.11 11,847.33 - 9,464.66 5,986,156.36 361,911.67 0.00 15,162.85 17,800.00 90.59 321.43 7,573.98 7,522.08 11,925.52 - 9,526.99 5,986,235.60 361,850.69 0.00 15,262.84 17,900.00 90.59 321.43 7,572.96 7,521.06 12,003.70 - 9,589.33 5,986,314.84 361,789.71 0.00 15,362.83 18,000.00 90.59 321.43 7,571.93 7,520.03 12,081.89 - 9,651.67 5,986,394.08 361,728.73 0.00 15,462.82 18,100.00 90.59 321.43 7,570.91 7,519.01 12,160.07 - 9,714.01 5,986,473.32 361,667.75 0.00 15,562.80 18,200.00 90.59 321.43 7,569.88 7,517.98 12,238.26 - 9,776.34 5,986,552.56 361,606.77 0.00 15,662.79 18,300.00 90.59 321.43 7,568.86 7,516.96 12,316.44 - 9,838.68 5,986,631.80 361,545.79 0.00 15,762.78 18,400.00 90.59 321.43 7,567.83 7,515.93 12,394.63 - 9,901.02 5,986,711.03 361,484.81 0.00 15,862.77 18,500.00 90.59 321.43 7,566.81 7,514.91 12,472.82 - 9,963.36 5,986,790.27 361,423.83 0.00 15,962.76 18,600.00 90.59 321.43 7,565.78 7,513.88 12,551.00 - 10,025.69 5,986,869.51 361,362.85 0.00 16,062.74 18,700.00 90.59 321.43 7,564.76 7,512.86 12,629.19 - 10,088.03 5,986,948.75 361,301.87 0.00 16,162.73 18,800.00 90.59 321.43 7,563.73 7,511.83 12,707.37 - 10,150.37 5,987,027.99 361,240.89 0.00 16,262.72 18,900.00 90.59 321.43 7,562.71 7,510.81 12,785.56 - 10,212.71 5,987,107.23 361,179.91 0.00 16,362.71 19,000.00 90.59 321.43 7,561.68 7,509.78 12,863.74 - 10,275.04 5,987,186.47 361,118.93 0.00 16,462.69 19,100.00 90.59 321.43 7,560.66 7,508.76 12,941.93 - 10,337.38 5,987,265.70 361,057.95 0.00 16,562.68 19,200.00 90.59 321.43 7,559.63 7,507.73 13,020.11 - 10,399.72 5,987,344.94 360,996.97 0.00 16,662.67 19,300.00 90.59 321.43 7,558.61 7,506.71 13,098.30 - 10,462.06 5,987,424.18 360,935.99 0.00 16,762.66 19,400.00 90.59 321.43 7,557.58 7,505.68 13,176.49 - 10,524.39 5,987,503.42 360,875.01 0.00 16,862.65 19,500.00 90.59 321.43 7,556.56 7,504.66 13,254.67 - 10,586.73 5,987,582.66 360,814.03 0.00 16,962.63 19,600.00 90.59 321.43 7,555.53 7,503.63 13,332.86 - 10,649.07 5,987,661.90 360,753.05 0.00 17,062.62 19,700.00 90.59 321.43 7,554.50 7,502.60 13,411.04 - 10,711.41 5,987,741.14 360,692.07 0.00 17,162.61 19,800.00 90.59 321.43 7,553.48 7,501.58 13,489.23 - 10,773.74 5,987,820.37 360,631.09 0.00 17,262.60 19,900.00 90.59 321.43 7,552.45 7,500.55 13,567.41 - 10,836.08 5,987,899.61 360,570.11 0.00 17,362.58 20,000.00 90.59 321.43 7,551.43 7,499.53 13,645.60 - 10,898.42 5,987,978.85 360,509.13 0.00 17,462.57 20,100.00 90.59 321.43 7,550.40 7,498.50 13,723.78 - 10,960.76 5,988,058.09 360,448.15 0.00 17,562.56 20,200.00 90.59 321.43 7,549.38 7,497.48 13,801.97 - 11,023.09 5,988,137.33 360,387.17 0.00 17,662.55 20,300.00 90.59 321.43 7,548.35 7,496.45 13,880.16 - 11,085.43 5,988,216.57 360,326.19 0.00 17,762.54 20,400.00 90.59 321.43 7,547.33 7,495.43 13,958.34 - 11,147.77 5,988,295.80 360,265.21 0.00 17,862.52 20,500.00 90.59 321.43 7,546.30 7,494.40 14,036.53 - 11,210.11 5,988,375.04 360,204.23 0.00 17,962.51 20,600.00 90.59 321.43 7,545.28 7,493.38 14,114.71 - 11,272.44 5,988,454.28 360,143.25 0.00 18,062.50 20,700.00 90.59 321.43 7,544.25 7,492.35 14,192.90 - 11,334.78 5,988,533.52 360,082.27 0.00 18,162.49 20,800.00 90.59 321.43 7,543.23 7,491.33 14,271.08 - 11,397.12 5,988,612.76 360,021.29 0.00 18,262.48 20,900.00 90.59 321.43 7,542.20 7,490.30 14,349.27 - 11,459.46 5,988,692.00 359,960.31 0.00 18,362.46 9/10/2009 9 :56 :03AM Page 8 COMPASS 2003.16 Build 69 I r' g ,A F, I � illl l l H:, ConocoPhillips(Alaska) Inc. -WNS r +l Western North Slope CD2 Alpine Pad I , � l � 1 Plan: CD2-176 r Plan: CD2 -176 1 CD2- 176wp03 • jl L. .P l ...m -- I I i ,� r Drilling Services u11� ' , Ali Clearance Summary `'r , ,, Anticollision Report 11 IIj 09 September, 2009 b Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad - Plan: CD2 -176 - Plan: CD2 -176 - CD2- 176wp03 III 11, I,II Well Coordinates: 5,973,895.84 N, 1,511,203.39 E (70° 20' 14.10" N, 151° 02' 54.51" W) 1 1 1 Datum Height: Plan: CD2 -176 (36.3 +15.6) @ 51.90ft (Doyon 19) 1,1 II_ Scan Range: 0.00 to 23,855.53 ft. Measured Depth. Scan Radius is 2,581.92 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied I I 'u1,11 Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference I IL Scan Type: 25.00 LI T Sperry drilling Services i II GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference 17:48, September 09 2009 9 CD2- 176wp03 Ellipsoid Color 36.30 To 23855.53 36 250 1750 - 2000 5000 - 6000 14000 16000 250 500 2000 2500 6000 7000 16000 16000 500 750 2500 3000 7000 8000 18000 20000 0 / 360 750 1000 3000 3500 8000 - 9000 20000 25000 300 1000 1250 3500 4000 9000 - 10000 ii 1250 1500 4000 4500 10000 12000 30 / 330.49 - 30 n r 1500 1750 4500 5000 12000 14000 n. J / /1 @: L = a ' � 1 ` . 4 , 2D2-46E a A\ � t ' ' lily 29 I ��I �I�� if ? i � , ' i�� s �^�;4� _CD2 -46E 60 / 300 � � 4'¢! 60 0 / 360 �50 ij 1� 30 / 330 30 r r ll j i , ' 101 e ea ES P ( �� N 1 f 11111j� /OA/ iiii r tdN111`�y� �" I I 111 / 4 r 64 ti! f ��. //,,////// � F r i "� / is °a 60 / 300 60 .,. ‘ 111.0 p,,„//,./...,,:i, k , c 1 , 2 90/270 g. 1 . egi 1(11.1(7/////://),X t - i IV iyi ; ``A r A i=,v iN ; aa �� f } I l i o i f +� a r d1 yp / - y= v �! \� t� 202 46 :.;'''" A , _ i - ` .'Net`'. e t & z, r .%y r `,,14,,10,4 . v` /,..;(4,1,,,40,4 Ii ' ,, ,141,- _ CD2 471wp0L r°: / ,, eb4. l '/. 4, i; v,,« ,„ 1;-"k , w �--' j et t _ 1 /ll % �i ....!'? R : rca �H_ 4i,e 90 r 1 { i'" � * t ;" � �tsa ��" «''[ N �k 90 / 270 ® �++ I i( 1 u rr w.at-1.71,-1'11'20 �y 202 -1E !r' } � � m 411"- i +, r f j rl`., v � w .... t gg o ` - 3 , i, R b §J" J7 '` ,f,,,..z , , V ss p ` Y i, - -it ae lM®, i, r l 1 ,� . f { s J ' , a . t .� -e5 � .V . g I ■ - - tiD2 -46¢ t i ` � l� ji�' sr A l . 9 +r} k t i :. z � i2 � i } r/ r » rc �s `"� a;, - < f i !` ai /yA ® vfi; �Z e 1 : triri 4Y I !� CD2 -18P / 1 F -, .. .. , 1 easy e ! _ % j ; ` ;t t tro .�ap 4.,, r <� . w. r ; `eE �A A �,VeltA 5 4 ]y l i .- i s,s. ' 1'yt. . a S r � l i j ,. ` W ArAlr 'D2 -78 RrgSurvey �, 1 C iss q pt / � /� , yt�i Lit I � _� �" 6 V i .e► �r h et ;'® P :D2 - 40� r �� l yl A • '` � � 120 / 240 ' t $ * 3 q"1 \ 1 y �� s ,3, 4�tq 1"ar�a�tr r 1 120 t .. C :� � gl � • r a �� f r r 9 1 � - D2 -777w 0 l r Le 0 � 0 . 4 , / D2- 177w -12 e t ;. # c sI vo erss Ffir_ p1 0 / 240 r } 11 f li b jR.a , CD2 - 73P -- 4Vor. + a r�N dr ° , I - � A, - \ �yv . 4 !$ . , � n .1+ 'Y / - 5 m s s ,, N,, , ► b� ' / p ,�``a,e /° 2D2 -7: Y 0111 r� �� i� °r i i i �'r +` w ` � / � .. , _ - - - - 4 r, a w d"'' ' 'A " " 4i ii ^ 7 ' ��i r 0: 0 r` �' `� ' O- s � � ' ' ID S 1_ .�� .:, - 1 5 0 / 210 t - ,f " ' - � 'A 150 D2 -78 RI Surve s ," r •"r, 1 , .m 9 15(} 2 10 l �.� /0 150 J �!'ba`�' 202 -7 �- , �i*:'�t�t� � � +s f'i _ 180 /�98p . D2 -7 - ..44, , - 1 180 / 180 2 D2 -OE D2- 31P61,' r CD2 -75 Ei�ili CD2 -72 D2-3' 1 D2-474 D2 -467P D2 -46 } D 2, CD2 -05L' CD2 -21 P81 D2 -46 Travelling Cylinder Azimuth (TFO +AZI) [ °] vs Centre to Centre Separation [25 ft/in] ConocoPhillips(Alaska) Inc. -WNS HALL1BURTON Western North Slope Anticollision Report for Plan: CD2 -176 - CD2- 176wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad - Plan: CD2 -176 - Plan: CD2 -176 - CD2- 176wp03 Scan Range: 0.00 to 23,855.53 ft. Measured Depth. Scan Radius is 2,581.92 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Welibore Name - Design (ft) (ft) (ft) (ft) ft CD2 Alpine Pad 40 CD2 -02 - CD2 -02 - CD2 -02 3,438.56 317.60 3,438.56 262.18 3,225.00 5.731 Centre Distance Pass - Major Risk CD2 -02 - CD2 -02 - CD2 -02 3,556.47 320.47 3,556.47 260.22 3,350.00 5.319 Clearance Factor Pass - Major Risk CD2 -02 - CD2 -02PB1 - CD2 -02PB1 3,438.56 317.60 3,438.56 262.18 3,225.00 5.731 Centre Distance Pass - Major Risk CD2 -02 - CD2 -02PB1 - CD2 -02PB1 3,556.47 320.47 3,556.47 260.22 3,350.00 5.319 Clearance Factor Pass - Major Risk a _ I CD2 -05 - CD2 -05 - CD2 -05 1,687.23 218.43 1,687.23 187.43 1,875.00 7.046 Centre Distance Pass - Major Risk CD2 -05 - CD2 -05 - CD2 -05 1,700.00 218.53 1,700.00 187.26 1,900.00 6.990 Clearance Factor Pass - Major Risk ^^ °� CD2 -05 - CD2 -05L1 - CD2 -05L1 1,687.23 218.43 1,687.23 187.43 1,875.00 7.046 Centre Distance Pass - Major Risk CD2 -05 - CD2 -05L1 - CD2 -05L1 1,700.00 218.53 1,700.00 187.26 1,900.00 6.990 Clearance Factor Pass - Major Risk ...�.. CD2 -09 - CD2 -09 - CD2 -09 4,399.08 471.50 4,399.08 343.74 4,175.00 3.690 Centre Distance Pass - Major Risk CD2-09 - CD2 -09 - CD2 -09 15,200.91 64751 15,200:91 233.66 15,375.00, 1.565 Clearance Factor Pass - Major Risk CD2 -09 - CD2 -09L1 - CD2 -09L1 4,399.08 471.50 4,399.08 343.74 4,175.00 3.690 Centre Distance Pass - Major Risk CD2 - 09 - CD2 - 09L1 CD2 - 09L1 15,200,91; 64751 15,20091 23356; 15,37550; 1.565 Clearance Factor Pass - Major Risk r -m CD2 -09 - CD2 -09PB1 - CD2 -09PB1 4,399.08 471.50 4,399.08 343.74 4,175.00 3.690 Centre Distance Pass - Major Risk CD2 -09 - CD2 -09PB1 - CD2 -09PB1 4,494.12 472.57 4,494.12 342.41 4,275.00 3.631 Clearance Factor Pass - Major Risk CD2 -11 - CD2 -11 - CD2 -11 3,179.69 459.44 3,179.69 391.77 3,275.00 6.790 Centre Distance Pass - Major Risk CD2 - 11 - CD2 - 11 - CD2 - 11 17,654.44 570.81 17,654.44 179.42 18,18650 1.458 Clearance Factor Pass - Major Risk CD2 -15 - CD2 -15 - CD2 -15 2,228.44 372.13 2,228.44 325.35 2,375.00 7.956 Clearance Factor Pass - Major Risk ill CD2 -15 - CD2 -15PB1 - CD2 -15PB1 2,228.44 372.13 2,228.44 325.35 2,375.00 7.956 Clearance Factor Pass - Major Risk CD2 -15 - CD2 -15PB2 - CD2 -15PB2 2,228.44 372.13 2,228.44 325.35 2,375.00 7.956 Clearance Factor Pass - Major Risk CD2.18 - CD2 - 18i - CD2 -18 1,797,31; 111.39 1,797 79,40 1,900.00 3.482 Clearance Factor Pass=4 Major Risk CD2.18 - CD2-18 - ; CD2 -18 1,817,22; 111.30 1,817.22,' 79.74, 1,925.00 3.527 Centre Distance Pass - Major Risk CD2 -18, - CD2 -18P61 - CD2 -18PB1 1,818.45 105.52 1,818.45 73.43„ 1,925.00 3.288 Clearance Factor Pass - Major Risk CD2 -21 - CD2 -21 _- _CD2 -21 2,395.63 108,80 2,395.63 67.73,!1 2,625.00 2.649 Clearance Factor Pass - Major Risk CD2 -21, - GD2 -21 - CD2 -21 2,418.16 108.54 2,418.16 68.17 2,550.00- 2.089 Centre Distance Pass - Major Risk CD2-21 - CD2 -21P131 - CD2 -21 PB1- 2595.53 ;108.80 2,395 67,73 2,525.00 2.649 Clearance Factor Pass - Major Risk CD2 -21- CD2.21PB1 - CD2 -21PB1 2,418.16 108.54 2,418 68,17 2,550.00 2.689 Centre Distance Pass - Major Risk CD2 - - CD2 - - CD2 -23 2,186.18 504.38 2,186.18 463.12 2,350.00 12.223 Centre Distance Pass - Major Risk CD2 -23 - CD2 -23 - CD2 -23 2,225.01 504.68 2,225.01 462.74 2,400.00 12.032 Clearance Factor Pass - Major Risk 09 September, 2009 - 17:34 Page 2 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Plan: CD2 -176 - CD2- 176wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad - Plan: CD2 -176 - Plan: CD2 -176 - CD2- 176wp03 Scan Range: 0.00 to 23,855.53 ft. Measured Depth. Scan Radius is 2,581.92 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD2 -24 - CD2 -24 - CD2 -24 2,056.97 318.67 2,056.97 281.10 2,325.00 8.482 Centre Distance Pass - Major Risk CD2 -24 - CD2 -24 - CD2 -24 2,073.89 319.08 2,073.89 280.74 2,350.00 8.324 Clearance Factor Pass - Major Risk CD2 -24 - CD2 -24PB1 - CD2 -24PB1 2,056.97 318.67 2,056.97 281.10 2,325.00 8.482 Centre Distance Pass - Major Risk • CD2 -24 - CD2 -24PB1 - CD2 -24PB1 2,073.89 319.08 2,073.89 280.74 2,350.00 8.324 Clearance Factor Pass - Major Risk CD2 -30 - CD2 -30 - CD2 -30 1,411.35 320.49 1,411.35 293.54 1,600.00 11.890 Centre Distance Pass - Major Risk CD2 -30 - CD2 -30 - CD2 -30 1,425.00 320.54 1,425.00 293.25 1,625.00 11.745 Clearance Factor Pass - Major Risk CD2-31 CD2 -31 - CD2 -31; 1,712.07 123.64 1,712?,07 92.27 1,925.00 3.941 Centre Distance Pass - Major Risk CD2-31 CD2 -31 - CD2 -31 1,728.35 123.87 1,728!,35 91.62 1,950.00 3.840 Clearance Factor Pass - Major Risk CD2-31 - CD2 -31PB1 - CD2-31PB1 1,712.07 123.64 1,712.07 92.27 1,925.00 3.941 Centre Distance Pass - Major Risk CD2-31 - CD2 -31 PB1 - CD2-31 PB1 1,728.35, 123.87 1,728.35 91.62 1,950.00 3.840 Clearance Factor Pass - Major Risk; CD2 -404 - CD2 -404 - CD2 -404 2,379.00 238.96 2,379.00 190.93 2,350.00 4.976 Clearance Factor Pass - Major Risk CD2 -464 - CD2 -464 - CD2 -464 36.30 240.05 36.30 239.04 36.48 237.451 Centre Distance Pass - Major Risk CD2 -464 - CD2 -464 - CD2 -464 397.41 241.85 397.41 233.45 400.00 28.818 Clearance Factor Pass - Major Risk CD2 -465 - CD2 -465 - CD2 -465 1,242.31 156.17 1,242.31 132.61 1,275.00 6.628 Centre Distance Pass - Major Risk ---� CD2 -465 - CD2 -465 - CD2 -465 1,266.26 156.34 1,266.26 132.35 1,300.00 6.515 Clearance Factor Pass - Major Risk CD2 -466 - CD2 -466 - CD2 -466 249.33 199.70 249.33 194.37 250.00 37.506 Centre Distance Pass - Major Risk CD2 -466 - CD2 -466 - CD2 -466 593.77 202.24 593.77 190.92 600.00 17.873 Clearance Factor Pass - Major Risk CD2 -467 - CD2 -467 - CD2 -467 1,164.36 158.89 1,164.36 137.63 1,225.00 7.472 Clearance Factor Pass - Major Risk CD2 -467 - CD2- 467PB1 - CD2- 467PB1 1,164.36 158.89 1,164.36 137.63 1,225.00 7.472 Clearance Factor Pass - Major Risk CD2 -468 - CD2 -468 - CD2 -468 1,218.42 91.57 1,218.42 69.63 1,275.00 4.175 Centre Distance Pass - Major Risk CD2 -468 - CD2 -468 - CD2 -468 1,240.65 91.57 1,240.65 69.22 1,300.00 4.097 Clearance Factor Pass - Major Risk CD2 -469 - CD2 -469 - CD2 -469 664.25 135.62 664.25 123.07 675.00 10.805 Centre Distance Pass - Major Risk CD2 -469 - CD2 -469 - CD2 -469 758.69 136.75 758.69 122.39 775.00 9.522 Clearance Factor Pass - Major Risk CD2 -470 - CD2 -470 - CD2 -470 832.16 109.30 832.16 93.15 850.00 6.766 Centre Distance Pass - Major Risk CD2 -470 - CD2 -470 - CD2 -470 855.16 109.55 855.16 92.99 875.00 6.616 Clearance Factor Pass - Major Risk CD2 - 72 - CD2 - 72 - CD2 -72 1,520.52; 40.82 1,520.52 15.79, 1,550.00 1.631 Clearance Factor Pass - Major Risk CD2 -73 - CD2-73 - CD2 -73 1,084.14 55,21: 1,084.14 36.21 1,100,00, 2,811 Centre Distance Pass - Major Risk CD2 -73 - CD2 -73 - CD2 -73 1,108.21 50 1 ,108.21 36.02 1,125400; 2.776 Clearance Factor Pass - Major Risk, CD2 -73 - CD2 -73PB1 - CD2 -73PB1 1,084.14, 55 21, 1,084.14; 36.21 1,100.09. Centre Distance Pass - Major Risk CD2-73 - CD2- 73PB1- CD2- 73PB1„ 1,108.21 56.30, 1,108.21 36.02, 1,125.00 2.776 Clearance Factor Pass - Major Risk, 09 September, 2009 - 17 :34 Page 3 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLI V TON Western North Slope Anticollision Report for Plan: CD2 -176 - CD2- 176wp03 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD2 Alpine Pad - Plan: CD2 -176 - Plan: CD2 -176 - CD2- 176wp03 Scan Range: 0.00 to 23,855.53 ft. Measured Depth. Scan Radius is 2,581.92 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD2 CD2 - 74 - CD2-74 695.46 33,52 695 18.50 700,00 2.231 Centre Distance Pass -_Major Risk, CD2-74 CD2 -74 - CD2 -74 719.91 33.69 719.91 18.15 725.00 2,167 Clearance Factor Pass - Major Risk, CD2 - 75 - CD2 - 75 - CD2 - 75 36.30 19.97 36.30 18.96 36.70 19.755 Centre Distance Pass - Major Risk CD2-75 CD2 -75 - CD2 -75 448.64 20.71 448.64 12.37 450.00 2.482 Clearance Factor Pass - Major Risk, Plan: CD2 -177 - Plan: CD2 -177 - CD2- 177wp02 250.00, 20.23 250.00 14.96 250.00 3.835 Centre Distance Pass - Major Risk Plan: CD2 -177 - Plan: CD2 -177 - CD2- 177wp02 600.62 24.18 600.62 111.25 600.00 11,870 Clearance Factor Pass - Major Risk Plan: CD2 -471 - Plan: CD2 -471 - CD2- 471wp04 423.98 99.94 423.98 90.88 425.00 11.028 Centre Distance Pass - Major Risk , - Plan: CD2 -471 - Plan: CD2 -471 - CD2- 471wp04 522.65 100.95 522.65 89.72 525.00 8.990 Clearance Factor Pass - Major Risk TDed: CD2 -78 - TDed: CD2 -78 - CD2 -78 RigSurveys 149.19 39.58 149.19 36.34 150.00 12.227 Centre Distance Pass - Major Risk TDed: CD2 -78 - TDed: CD2 -78 - CD2 -78 RigSurveys 199.19 39.98 199.19 35.66 200.00 9.250 Clearance Factor Pass - Major Risk Survey tool proaram From To Survey /Plan Survey Tool (ft) (ft) 36.30 1,000.00 CD2- 176wp03 CB- GYRO -SS 1,000.00 23,855.53 CD2- 176wp03 MWD +IFR- AK- CAZ -SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 09 September, 2009 - 17:34 Page 4 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS IHALLIBURTON Western North Slope Anticollision Report for Plan: CD2 -176 - CD2- 176wp03 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: CD2 -176 (36.3 +15.6) @ 51.90ft (Doyon 19). Northing and Easting are relative to Plan: CD2 -176. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150.00 °, Grid Convergence at Surface is: -0.99 °. J rm -n0. rn? -no f•n? nn to Ladder -9- CO2- 09,CO2- 09PB1. V4 aK • -6- CD2- 11,CD2- 11,CO2.11 V7 • rA �< �a 1 - - -- 1 C122.15,CO2.15,CO2.15V3 �� !« # y �� , I — — CD2.15,CD2.15PB1,CD2.15PB1 V1 ri , ,' pia I 2250 1 1 — CD2.15,CD2.15PB2,CD2.15PB2 V2 2 & • �. ► • - la :. 9 - x , , j r - ! ri-' "; .6:7.:!. C� 18,CD2.18,CD2 - 18V19 9y O Id ' !'� � I � ■ 1 $ CO2.18,CD2.18P81,CD2- 18P811f5 ... ,:........ ■: r--- 71 ti � ' + � y � + ; �� 2. ;� _ -9- CD2.21,CD2.21,CO2 -21 V19 I ill �� ' � � � �� -e- CD2- 21,CD2.21PB1,CD2.21PB1 V7 p a . �,. ., • ,_, a r te. I — 1*-- CD2 -24, CD2.24,CO2.24 VO 1500 ;•!i' i�.i�r' rt:i.. ■� .x $ CD2- 24,CD2.24PB1,CO3- 24PB1Ul " Fi �1 � t ? f '.' s . I I I -e — CD2- 30,CD2.30,CD2.30 V31 ( ' , i � rf * ill ` I t , r . '. ', 3, l I I ! {1' - CD ? -31, CD2- 31 ,GD2 -31 V7 1. Q? r: r � t ,� t _ I I ___ I CD2- 31,CD2- 31PB1,CO2.31PB1V4 1 ' r . d ` 1119.ZT:17;. i +` ,'; I I I CD2.404,CO2- 404,CO2 -404 V5 r- c 1 ;I ( .1- fi y V . I I a i .r �2 'r . a I I - CD2.464, CD2.464,CO2 -464 VO o 7 ,. 1 �, s q 1 — CO2- 465,CD2- 465.CD2- 465V1) -- CD2.466 ,CD2- 466,CD2- 466Vti Q? 1 1 1 1 1 " . . -4- CD2.467,CO2-467,CD2 -467V0 • 1 I q� �e , , , � , I -e- CD2.467, G02- 467PB1,CD2- 467PB1 VO U w yY:r7 I I I I I Y'• I I I I I CD2 -468, CD2 "468,CO2 "468VO - - ' J,'0 I I 1 I 1 0 � - — CD2- 469,CO2- 469,CD2 -469VO - CO2.470,CO2 2.CD .72 0 4500 9000 13500 18000 22500 VI - CD2- 72,CD2- 72,CD2 -72 V1 Measured Depth (4500 ftlin) -$- cD2- 73, CD2- 73,CD2 -73VO -4 cC2 7 '0 - a2'2°0 1 ? - 0' '2°91 \D 09 September, 2009 - 17:34 Page 5 of 6 COMPASS ConocoPhillips(Alaska) Inc. -WNS IHALLIB RTON Western North Slope Anticollision Report for Plan: CD2 -176 - CD2- 176wp03 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor CO2- O9,CO2- 09,032 -09 V2 1. 1 II! I I` + � • 3 CD2- 09,CO2- 09L1,CO2- 09L1V1 ! ! CO2- 09,CO2- 09P61,CO2- 09PB1V4 CO2.11,CD2.11,CO2 -11 V7 �� - j s p -3(— CO2.15,CO2- 15,CD2 -15V3 I - 3 , � , T :11 1 •u ate � ,.�!■ _._� . - I Ral i1 I i - . � - - - CD2- 15CD2- 15PB1CD2-15P81 V1 111 . 1.. r+� �w gk�c - -Q- CO2- 15,CO2- 15PB2,CO2.15P82V2 _III _ -X CO2- 18,CO2- 18,CO2 -18V19 J - -- CO2.18,CO2- 18PB1,CO2 -18P81 V5 .�yI 'I � `' r�, fit � I �,f � � I , -$- CO2.21.0O2- 21,002 -21V19 ri 5 g �i4 s ' • f CO2- 21.CD2- 21P81,CO2 -21P81 Vl +. {{ t' !' aia } L7 [ � CD2- 24,CD2- 24,CD2.24V0 0 = I Ji �. f ! �.', !_/ t'PI lei d �'S � f � � � ' -. � - ! 1 CCC - r �I� �y * F� �i� s!j. :�j �.. s..�„ „s; a'� - 9 - CO2.24.0O2-24P81.0O2 -24 B1 V1 �� a - CD2- 31) -30, CD2 -30 V31 co X00 ; ;'l# ;UlU _ r� : ^ �x r'y - -e- CO2- 31,CO2- 31.0O2 -31 V7 �� ,I �+� .� ` r * �'. - 9 - CO2.31,CD2 -31PB 1,CO2.311' B 1 V4 fl I + } 1 -- I .1 ., _ -1- 002.404, CO2- 404,CO2 -404 V5 ..,. , y -j{- CO2.464,CO2- 464,CD2 -464V) , ' r '` ! -- CO2-48&CO2-465,CO2-465V0 � �' w iI - - L _ - - CO2 -486, CO2.486.0O2 -466 Vb i -.- 1 ' + i ! -- CO2- 467,CO2- 467,CD2 -467V0 _ M _T [ ! € M _ +•` I _ 0 - CO2.467,CO2- 467PB1,CO2- 467PB1 V0 d . CD2 -46s Cox -46s cD2 -46s Va 4- CO2.469,CD2.480.0O2 -469VD CO2 -470, CD2- 470,CO2 -470 V0 aaa -- CO2.72,CD2.72,CO2 -72V1 0 ia] i ix x i o lX.j e- CO2-73,CO2-73.0 02-73 V0 Measured Depth(40001bin) - CO2 - 73,002- 73P81,CO2.73P81 VU 09 September, 2009 - 17.34 Page 6 of 6 COMPASS Project: Western North Slope ConocoPhillips Site: CD2 Alpine Pad CD2- 176wp03 Well: Plan: CD2 -176 Wellbore: Plan: CD2 -176 HALL[BURT® CD2- 176wp03 Quarter Mile View Sperry Milling 20000 - O" I G IP 17500- tr o 0 45000 N I CD' -468 ?12500 Go cna. o � G G p 2 b G 01 0 0 GOZ 465 L C21: 4 I I , 1Pe' f ip v 1. O ! God' 2, U) 1 i de 10000 \ cp-k-- - a GO ' I A G ®�" G A L O G0 'V „ �\ Ga iikIN " �� j i G 7500 G a' " Ilii 1 �., c02 46 z '■ \ t -20000 -17500 -15000 -12500 -10000 -7500 -5000 -2500 0 West( -) /East( +) (2500 ft/in) 1 4 � .;:"'...1.1 ir,II, , 0 t r • of r I ¢` -tom' ',,. -_,----- .--- 4 41. 4211 ,/ NA HUM ,,-----.'" ,,, - - - ' 7 / ' r /I/ ' . I : 1 '4111111 1. , . . ' , ''' : \ .... **--v ' -.-,,. ''..\-...\; N>,--.. ---.-.,:„.:.., -- ' - --77.7 .. .: /j / 11111 `C 7. _.--";" ///// .. I. \ .,, \ \";:\ ,..... \ \ ,..., f // N ......„::::_v": ,---" ....---- .....-- , . ) , J ''' ) , • i ; •1 CD 2-1 7 6wp 03 Toe 176wp03 eel 1 Operator: CorwcoPOOYbt(Akvk*bc. -WN5 G940orlec+bn -0.99 • Job91 YN /A Aoki Westan N orlk Sops E9{11Nk Declnabn. 2160 • AR No: IN /A Ww: CD2- 176w903 0p: 80J0 • APINo fN /A Ply: RN /A 0oyeypa 100 f1 System (NO)Relerence: Mean Sea levN surlselowbn Origlnd VS Plane 320.76 Pae ww: Pkn:CD2 -n6 X. 151100339 ft View VS Plane: 320.76 RIM WW1. 51.90 8 Y: 5973895.54 ft Un8 System: API Booed /FPS Section NS) Reference: 561 Comments: POOL: • ,n : 8 o N r N P O N N p M p Q V V Q 8 8 cg § CD2- 176wp03 Plan: 16783' to 23855.53' MD _ - - - - ; CD2 -09: 12617' to 16409' MD CD2 -11: 13760' to 18186' MD .5991900 CD2 -21: 13264' to 19359' MD 5990900 5989900 • 0 ._,.... _ ....................... ...__.._ ... .. -.. ........._ .,.... ......,._ -. ......... ...........- 5988900 o z • ....... _, - _._.... .._..__ .........._ 5987900 . ' Section View — CD2- 176wp03 Plan -- -CD2 -09 CD2 -11 CD2 -21 • ......... .- ._...._ -_ ..........5986900 ((fi�tt 1. 1 .._..._... __ -- 5985900 Il yrA.,...... _— ____ _.__._ ........... - 5984900 -___- _ ._� _____ *' ............. • 5982900 o - .: ". �. � .. to ■ 0) N '. - -- 7700 Verf icd Sect ton Bong 'Mew VS Plane" I Combo Preview Page 1 of 1 (CD2- 176wp03 Toolbox)ds) 9/10/2009 9:33 AM �, Closest in POOL Closest Approach: Reference Well: CD2- 176wp03 Plan Offset Well: CD2 -11 Coords. - Coords. - ASP ASP 3 -0 ctr -ctr I,,e. Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea 14( +) /S( -) View VS Distance. 11IIN .r Depth Angle Azi. TVD E( +) /W(- (32076) Comments Depth Angle Azi. TVD E( +) /W(- (320.76) Comments POOL Min PUUL Min Distance (57273 ft) Distance (572.73 ft) in POOL (16783 - in POOL (16783 - 1.7 23855.53 MD) to 23855.53 MD) to CD2 -11 (13760 - CD2- 176wp03 Plan 5 572,73 Y @' ;,'11 i -'. 17650 90.59 321.43 752455 5985863 1501974 1511246 18186 MD) 18186 92.03 32002 7144852 5985603 1501633 1511631 (13760 - 18186 MD) Closest Approach: Reference Well CD2- 176wp03 Plan Offset Well CD2 -09 Coords. - Coords. - ASP ASP 3 - ctr . d 1 1 1 Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. 1 x: Depth Angle Azi. TVD E( +) /W(- (320.76) Comments Depth Angle Azi. TVD E( +) /W(- (320.76) Comments PUUL Min PUUL Min Distance (1028 ft) Distance (1028 ft) ......-.. in POOL (16783 - in POOL (16783 - ° 23855.53 MD) to 2385653 MD) to > CD2 -09 (12617 - CD2- 176wp03 Plan 1028 r I i 16783.94 85 321.43 7520.955 5985177 1502502 14246.78 16409 MD) 16409 92.08 330.55 7115.898 5985256 1503443 13725.56 (12617 - 16409 MD) ,, w ■ Closest Approach: Reference Well CD2- 176wp03 Plan Offset Well CD2 -21 Coords. - Coords. - ASP ASP 3 - ctr - ctr Iri;ea Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. 1 11 a Depth Angle Azi. TVD E( +) /W(- (320.76) Comments Depth Angle Azi. TVD E( +) /W(- (320.76) Comments • POOL Min POOL Min Distance (188257 Distance (188257 ft) in POOL (16783 ft) in POOL (16783 - 2385653 MD) to - 2385653 MD) to CD2 -21 (13264 - CD2- 176wp03 Plan 1882,6 1... . 18350 90.59 321.43 7517.34 5986418 1501547 1581237 19359 MD) 19359 93.76 331.14 7122161 5985294 1500090 15831.56 (13264 - 19359 MD) PoolSummaryl 9/10/2009 9:42 AM _ID REV DATE BY CK APP DESCRIPTION REV DATE BY C APP DESCRIPTION 1 4/18/07 CZ DB C.A. ISSUED PER K07041ACS 2 4/21/08 CZ GD C.A. UPDATED PER K080010ACS ,./.1 \- c02 ACCESS ROAD o H A 1 �� PIN LOCATION OF z " � ti , I °. ECT I THIS SURVEY =/DRILL •ITE CD- / Mr' V .. 111 M 111 " 1 1r 7/— Z o 1 Af /2 Z ALPINE SATELLITE DEVELOPMENT \ � ,,, / ` VICINITY MAP NOT TO SCALE { 1ir , . 1 1�m �� rr~ � � 2[.- ASPC I 1 , – N t N 1 PLANT 1 1 , 4' . N �, r 06'03'45 " 0 1 z � � N CD-2 � LC11F ''� ' 1.1k-., � ��,, U re I Rk PAD ._ w l 1 • N 1 . ' nyI 4 Z Z >a 1I o l''''= * \ 11! w ■ T ll t 1 ) 1 1 � , ` QANNIK � CONDUCTORS - �� - ' cyp.) --,-1-_--- ----- 11--11E-1 w« 1 , i , , , N rn 79`0 8 UU U O V s U c. V° U U U U U U DESIGN SHOULDER QANNIK PAD LEGEND: KU U KP I K O PROPOSED CONDUCTOR ‘, if LCIAF • EXISTING CONDUCTOR .........._. ..... u„"e OMB (907) 670 -4739 Alpine Survey Office ALPINE MODULE:CD20 UNIT: QNK CWnocWPhillips ALPINE PROJECT QANNIK WELL CONDUCTORS Alaska, Inc. AS —BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 07- 02 -18 -1 4/1/07 CE —CD20 -139 1 OF 3 2 to R I L ConocoPhillips Alaska, Inc. Post Office Box 100360 • • Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 September, 10 2009 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2 -176 Dear Sir or Madam: r ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the CD2 drilling pad. The intended spud date for this well is September 20, 2009. It was originally intended that the CD2 -60L1 well would be spudded on this date, however due to unforeseen issues with the pre -rig work associated with the well; it is unlikely that ConocoPhillips will achieve this goal. In an effort to keep drilling operations fluid, a permit and drilling plan is hereby submitted to drill the CD2 - 176 well using Doyon Rig 19. ConocoPhillips realizes that this permit application is being submitted at short notice. In this case however, it was not anticipated that there would be a need to drill the CD2 -176 well this year. Your timely review of the permit application would be greatly appreciated. i It is planned that the CD2 -176 will be completed as a horizontal producer in the Nechelik reservoir. The well will be flowed back to mitigate reservoir damage and will then hooked up to begin production. • It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing zone. It is planned to pump lead cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At CD2, there has not been a significant show of shallow gas or gas hydrates through the surface hole interval. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10 -401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program. 3. A drilling fluids program summary. 4. Pressure information as required by 20 ACC 25.035 (d) (2). 5. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. • • If you have any questions or require further information, please contact Nina Anderson at 265- 6403, or Mark Chambers at 265 -1319. Sincerely, Nina Anderson Drilling Engineer Attachments cc: CD2 -176 Well File / Sharon Allsup Drake ATO 1530 Mark Chambers ATO 1566 Nina Anderson ATO 1706 Liz Galiunas ATO 1704 Ryan Robertson ATO 1708 Lanston Chin Kuukpik Corporation • Ramirez, Darlene V (DOA) From: Seamount, Dan T (DOA) Sent: Monday, September 28, 2009 9:23 AM To: Ramirez, Darlene V (DOA) Cc: Foerster, Catherine P (DOA); Davies, Stephen F (DOA); Norman, John K (DOA) Subject: Re: 209 -098 Approved but someone needs to teach cp how to fill out the paper wright. Sent from my iPhone On Sep 25, 2009, at 4:05 PM, "Ramirez, Darlene V (DOA)" <darlene.ramirez @alaska.gov > wrote: > «S45C- 209092513430.pdf» > The message is ready to be sent with the following file or link > attachments: > S45C- 209092513430.pdf > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C- 209092513430.pdf> 1 • • TRANSMITTAL LETTER CHECKLIST WELL NAME d, ? //( d 2 - PTD# 7� (..L) /Development Service Exploratory Stratigraphic Test Non - Conventional Well /� / / FIELD: &I /lit // J` ` ` I� POOL: Aj 1&a / U ;/i Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Pool COLVILLE RIVER, NECHLK UND OIL - 120177 — —Well Name: COLVILLE RIV UNIT CD2-176 Program DEV Well bore seg PTD#: 2090980 Company CONOCOPHILLIPS ALASKA INC Initial Class /Type DEV / PEND GeoArea 890 Unit 50360 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surf location in ADL 380075; shallow wellbore also passes through ADL 0025530 & ADL 387212; 1 3 Unique well name and number Yes top of prod inteval in ASRC NPRA 01; prod interval crosses ADL 387211; TD in ADL 380095. 4 Well located in a defined pool Yes NEW OIL POOL - NECHELIK UNDEFINED OIL POOL: production interval lies beneath Alpine Oil 5 Well located proper distance from drilling unit boundary Yes Pool (see CO 443B). Meets statewide spacing requirements: only well in Nechelik Undef Oil Pool 6 Well located proper distance from other wells Yes within Sections 21 & 28 of T12N, RO4E; > 2 -1/2 miles from external boundary of Colville River Unit. 7 Sufficient acreage available in drilling unit Yes 1 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 9/15/2009 114 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA iv 1 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre- produced injector: duration of pre- production less than 3 months (For service well only) No 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No aquifers 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No 22 CMT will cover all known productive horizons Yes 2nd stage cement to cover Qannik. Slotted liner in Prod zone. 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waster to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. CD2 -75 is closest well at 12' @ 449'md 27 If diverter required, does it meet regulations NA Diverter waiver requested. No shallow gas issues in CRU. 20 AAC 25.035(h)(2) Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure 3425 psi( 8.7 ppg EMW) Drilling with 9 -9.5 ppg mud GLS 9/23/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP = 2668 psi Testing BOP's to 3500 psi 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 1 133 Is presence of H2S gas probable No H2S not reported at CRU. Rig has alarms and sensors. 34 Mechanical condition of wells within AOR verified (For service well only) NA J 1 35 Permit can be issued w/o hydrogen sulfide measures Yes None expected, but H2S detection systems & alarms will be used. Mud scavengers available. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 8.7 ppg EMW; production interval will be drilled using 9.2 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA SFD 9/15/2009 38 Seabed condition survey (if off- shore) NA 1 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Public NEW POOL - NECHELIK UNDEFINED OIL POOL: will be located within geographic boundaries of Alpine Oil Pool, but beneath ate Date Date Commissioner: Commissioner: Commissioner the Alpine Oil Pool as currently defined by CO 443B. To the east, the Nechelik reservoir is included in the Fiord Oil Pool (see CO j J7 . ro r J n 9 / 6 43 569)spacing , but CDq2 -176 uirements: lies only 1 -3/4 m well i Nechelik s west of the Undef Oil SW boundaPool ry of within the S. Fior 21 & Oil 28 Poo of Tl. 12N As proposedwell , CD2 -176 lies > 2 -1/2 me es statewide from 7 �_ v/ / / � re, mows external Ja r2-)T�